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Home My WebLink About203-1831. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: 4,259; Total Depth measured 8,405 feet 5,025; 6,005 feet true vertical 7,844 feet N/A feet Effective Depth measured 4,259 feet N/A feet true vertical 3,968 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4,750psi 10,530psi 3,060psi 3,450psi 6,870psi 10,160psi 1,512' 1,512' Burst Collapse 1,500psi 1,950psi Production Liner 5,731' 8,341' Casing Structural 5,246' 7,801' 5,752' 8,362' 139'Conductor Surface Intermediate 20" 13-3/8" 118' 1,491' measured TVD 9-5/8" 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-183 50-133-20529-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA018142 Kenai Gas Field / Pool 6 Sterling Kenai Beluga Unit (KBU) 33-06X Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 139' 1 0716 0 270 38 Chad Helgeson, Operations Engineer 323-304 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 647 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 chelgeson@hilcorp.com 907-777-8405 N/A p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:02 pm, Aug 04, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.08.04 15:55:41 - 08'00' Noel Nocas (4361) Rig Start Date End Date E-Line 6/13/23 Future 06/13/2023 - Tuesday Travel to KGF from YJ shop. PJSM and permit. Travel to location KBU 33-06X. Spot equipment. Well house is out of line w/ well head. Remove well house. R/U YJ E-Line. PT surface equipment to 2500 PSI. Test good. Drain lubricator to blow down tank. RIH w/ Gun ONE 6' x 2" / Switch / Gun TWO 6' x 2" with well flowing at 26 PSI. Made tie in pass. Correlation log sent to town for approval. Town approved correlation log. Position Gun ONE at Sterling P4 B2L zone at 4150' to 4156'. CCL to TS = 15.5 / CCL depth will be 4134.5' to place TS at 4150'. Fire Gun ONE. PSI start 26 / 5 Min 28 / 10 Min 28 / 15 Min 28. Pull up hole. Position Gun TWO at Sterling P4 B1 zone at 4087' to 4093'. CCL to TS = 8.5' / CCL depth will be 4078.5' to place TS at 4087'. Fire Gun TWO. PSI start 28 / 5 Min 28 / 10 Min 28 / 15 Min 28. POOH. OOH. Lay down Gun ONE and Gun TWO. All shots fired. Light to medium coating on guns. Water soluble. End cap had large sample on it and was dry. P/U Gun THREE. RIH w/ Gun THREE 15' x 2" with well flowing at 28 PSI. Made tie in pass. Correlation log sent to town for approval. Town approved correlation log. Position Gun THREE at Sterling P4 B2U zone at 4119' to 4134'. CCL to TS = 16' / CCL depth will be 4103' to place TS at 4119'. Fire Gun THREE. PSI start 28 / 5 Min 26 / 10 Min 26 / 15 Min 26. POOH. OOH. Lay down Gun THREE. All shots fired. End cap had a thick mud in it. Stand by for instruction on possible GPT run. Decision made to return to this well possibly in 2-3 days. RDMO YJ E-Line. Move and spot YJ E-Line to 12-17. Return YJ crew to base. Plan forward: YJ E-Line to perforate 12-17 in morning. Daily Operations: 06/15/2023 - Thursday Travel from YJ shop to KGF. PJSM and permit. Travel to KBU 33-06X. MIRU YJ E-Line. RIH w/ 30' x 2" Gun ONE to shoot Sterling P4 at 4050' to 4080'. Made tie in pass. Sent log to town. Town approved. Position 30' x 2" Gun ONE across Sterling P4 zone at 4050' to 4080'. CCL to TS = 11' / CCL to be at 4039' to place TS at 4050'. Shoot Gun ONE. POOH. Start PSI 29 / 5 Min 20 / 10 Min 20 / 15 Min 20. OOH. Lay down Gun ONE. All shots fired. Engineer requested GPT run. Set up tools. RIH w/ GPT w/ well still flowing. Found FL at 3750'. Sent log to town. Town not good w/ fluid results of Gun ONE. POOH. RDMO YJ E-Line. YJ crew and equipment return to base. Plan forward: Town exploring options on well including a patch. Travel to KBU 33-06X from KU 12-17. MIRU YJ E-Line. PT surface equipment 250 / 2500 PSI. Test good. Drain lubricator to blow down tank. RIH w/ GPT with well flowing at 30 PSI. Found FL at 4170'. Deepest perf is 4156'. Tagged fill at 4255'. Send log to town. POOH. OOH. Lay down GPT. Night cap well. Secure equipment. SDFN. Return crew to YJ shop. Plan forward: Will be perforating 60' of Sterling P4 sands tomorrow morning. 06/14/2023 - Wednesday Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 33-06X 50-133-20529-00-00 203-183 Rig Start Date End Date E-Line 6/13/23 Future Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 33-06X 50-133-20529-00-00 203-183 Travel to KGF office from YJ shop. PJSM & permit. Travel to location. MIRU YJ E-Line. Remove well house. PT surface equipment 2500 PSI. Test good. Drain lubricator fluid. RIH w/ GPT. Flowing 26 PSI at surface. Found FL at 4160' below all perfs. Flowing BHP 46. Sent log to town. POOH. OOH. Lay down GPT. Assemble and arm 2-1/8" x 10' strip gun. RIH w/ 2- 1/8" x 10' strip gun to shoot P4 B1U zone at 4020' to 4030'. CCL to TS = 10'. CCL will be at 4010' to place TS at 4020'. Made tie in pass. Sent log to town. Town approved. Fire strip gun. Although tubing PSI dropped, we were blown up hole by fluid rush. Worked wire / tools for 35' then pulled free. POOH. PSI dropped from 26 to 15 flowing. 17' short of surface kinked wire above rope socket hung up in grease head. Worked wire / tools and cleared tree. Lay down strip gun. All shots fired. Wire badly kinked above rope socket. Slip wire and re-head. RIH w/ GPT. Found FL at 3692'. Pulled up hole to 3450' and stand by to see if FL increasing for 45 minutes. (17:15) Logged back down hole from 3450' and found FL at 3695'. Send both GPT logs to town. POOH. RDMO YJ E-Line. YJ crew return to base. 06/29/2023 - Thursday 06/17/2023 - Saturday AK E-line arrives at KGF office, sign in, obtain PTW, hold PJSM. Well flowing at 27.8 psi / 535 mcfd. Travel to 41-7 pad, spot equipment and RU. MU tool string - Wt. bar, GPT, junk basket w/ 2.88" gauge ring MU to well head and PT 250/2500psi. Pass. Open swab and RIH logging GPT survey from surface. Ran through B1U top perforations at 4050'-4080' seeing temperature cooling then setting down at 4087' (top of B1 perfs at 4087'-93'). No fluid detected. Worked tool at 4087' attempting to pass obstruction. No joy, POOH. OOH. Removed junk basket/gauge ring from GPT. Open swab and RIH. Well flowing at 29.6 psi / 627 mcfd. Ran log survey through previous obstruction and tagged PBTD at 4222'. Fluid level detected at 4156'. Lowest perfs at 4150'-4156'. Good look at temperature deflection through perforations with most cooling at B2U perforations (4119'-4134'). POOH. OOH. Secure well. RDMO. Casing patch on hold while production flows and monitors well performance. Rig Start Date End Date E-Line 6/13/23 Future Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 33-06X 50-133-20529-00-00 203-183 AK E-line arrives at KGF office, signs in, obtains PTW and holds PJSM. Mobilize equipment to 41-7 pad. Spot, RU units and MU lubricator and PCE on well head. MU junk basket w/ 2.88" GR and add to GPT. (14' CCL to GR) Move tools and lubricator to well head and PT 250psi/2500psi. PASS. Open swab (15 psi) and RIH w/ GPT/JBGR. Ran down to 4087' and set down at top perf interval 4087'- 4093'. No fluid level detected but some suspended fluid streams were noticed in well bore. POOH. OOH. LD GPT/JBGR and MU casing patch tool string. CCL, 2-1/8" MSST and Owen XSpan casing patch for 3-1/2"-9.3#. (48' OAL) Patch length top element to btm.element - 37.0' Patch drift ID - 2.25" CCL to top element - 9.7' RIH to 4030', get up weights and CCL correlation. RIH and patch sets down at 4087'. Confirm setting depths, PU and set patch at 4046'-4083'. (Over perfs @ 4050'-4080'). POOH. OOH. LD lubricator, setting tool and patch running gear. Redress multi-stage setting tool and MU second patch (21'). Patch length top element to btm. element - 21.5' Patch drift ID - 2.25" CCL to top element - 9.7' PU and stab on well. Open swab and RIH. Tag patch #1 at 4043' and PU ~10'. CCL depth @ 4004.8' - top element 4014.5' - bottom element 4036'. Set patch isolating perfs 4020'-4030'. POOH. OOH. Drop two soap sticks, secure well and RD. 07/18/2023 - Tuesday TOC @ 2,825' CBL 6/22/2022 TOC @ 4,259' 6/22/22 Tubing punch 4,400'-4,403 6/18/22 5,025' CIBP w 28' cmt 6/18/22 6,005' CIBP w 25' cmt top (9/18/21) PBTD: 4,259' MD/3,968' TVD TD: 8,405' MD/7,844' TVD Perforations: Sterling P4-B1U 4,020'-4,030' 2" 6spf (6/29/23) - Patched Sterling P4-B1 4,050'-4,080' 2" 6spf (6/15/23) - Patched Sterling P4-B1 4,087'-4,093' 2" 6spf 6/13/23Sterling P4-B1 4,087'-4,093' 2-3/8 5spf 6/26/22 Sterling P4-B2U 4,119'-4,134' 2-3/8 5spf 6/26/22 Sterling P4-B2 4,119'-4,134' 2" 6spf 6/13/23Sterling P4-B2L 4,150'-4,156' 2-3/8 5spf 6/26/22 Sterling P4-B2L 4,150'-4,156 2" 6spf 6/13/23 Sterling C2 5,045-5,077' 2-3/8 6spf (9/24/21) - Plugged Control lines: Red 1/4" control line: squeezed 1.5 gal cmt (9/19/21)Yellow 1/4" control line: squeezed 1.5 gal cmt (9/19/21)Green 1/4" control line: squeezed 1.5 gal cmt (9/19/21) Excape Mod Perfs MD (RKB):Module 20 - 6,119'- 6,129'Module 19 - 6,196'- 6,206'Module 18 - 6,279'- 6,289'Module 17 - 6,444'- 6,454'Module 16 - 6,543'- 6,553'Module 15 - 6,681'- 6,691'Module 14 - 6,724'- 6,734'Module 13 - 6,781'- 6,791'Module 12 - 6,858'- 6,868'Module 11 - 7,084'- 7,094'Module 10 - 7,122'- 7,132'Module 9 - 7,169'- 7,179'Module 8 - 7,240'- 7,250'Module 7 - 7,301'- 7,311'Module 6 - 7,379'- 7,389'Module 5 - 7,505'- 7,515'Module 4 - 7,791'- 7,801'Module 3 - 7,967'- 7,977'Module 2 - 8,102'- 8,112'Module 1 - 8,197'- 8,207' 3-1/2" x 9-5/8" TOC: 4,750' MD (1/22/04 CBL) Excape System Details * BHP monitoring line volume tank located from 6,055' - 6,093' KBU 33-6X Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. Permit #:203-183 API #:50-133-20529-00-00 Prop. Des:FED A - 028142 KB Elevation:82' (21' AGL) Latitude: Longitude: Spud:12/13/2003 TD:1/2/2004 Drive Pipe20" K-55 133 ppf PE Top BottomMD 0' 139' TVD 0' 139' Surface Casing13-3/8" K-55 68 ppf BTC Top BottomMD 0' 1,512'TVD 0' 1,512' Cmt w/ 320 sks Intermediate Casing9-5/8" L-80 47 ppf BTC Top BottomMD 0' 5,752' TVD 0' 5,246'Cmt w/ 705 sks Class G in 12.25" OH. Volumetric ToC estimate: 3053' with 50% washout, 1704' with no washout Production Tubing3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rdMD 0' 8,362' TVD 0' 7,800'Cmt w/ 1,150 sks of class G cmt Tag fill @: * 7,994' w/ Dynacoil (5/27/2010) * 7,876' w/ Dynacoil (3/2/2010) * 7,915' w/ Dynacoil (5/12/2009) Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 33-6X Kenai Peninsula Borough 4,020' - 8,207' 1.3º / 100 ft @ 1,500' 1/9/2004 D Ambruz Lease: State: Perf (TVD): Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 3,773' - 7,647' 8º 5.5º RKB:(AMSL)21' (AGL) 7/19/2023 Slickline tag w/ 2-1/4" LIB. Indicated "pinched in" pipe @ 7534' kb. 2-1/2" bailer got stuck @ 6,127' kb. (4/19/12) 9-5/8" x 12.25" TOC: 3,053' MD (Vol estimate with 50% washout) 5,752' 9-5/8 CSG * MITIA to 1500 psi Passed 9/19/21 C2 P4-B2L P4-B2 SCHEMATIC Owen XSpan Patches: 4,014.5'-4,036' 4,046'-4,083' (7/18/23) P4-B1U P4-B1L P4-B2U P4-B1 Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/25/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230725 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-34 50283201860000 222039 6/29/2023 AK E-LINE Perf-ProductionProfile BRU 223-34 50283201880000 223041 7/14/2023 AK E-LINE CBL/Perf BRU 223-34 50283201880000 223041 7/16/2023 AK E-LINE Perf BRU 244-27 50283201850000 222038 6/30/2023 AK E-LINE Perf END 1-01 50029218010000 188037 7/9/2023 AK E-LINE Plug/Cement END DIU 1-01 50029218010000 188037 7/7/2023 AK E-LINE Cross-Flow-Detect GO 8 50133206510000 215077 7/13/2023 AK E-LINE Perf KBU 33-06X 50133205290000 203183 7/18/2023 AK E-LINE GPT/Patch PBU F-29B 50029216270200 211147 7/8/2023 AK E-LINE CIBP Please include current contact information if different from above. T37872 T37873 T37873 T37874 T37875 T37875 T37876 T37877 T37878 KBU 33-06X 50133205290000 203183 7/18/2023 AK E-LINE GPT/Patch Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.25 12:04:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230711 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 22-06 50133205500000 205054 7/6/2023 YELLOW JACKET CBL KBU 22-06 50133205500000 205054 7/2/2023 YELLOW JACKET CBL/PERF KBU 33-06X 50133205290000 203183 6/14/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/29/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/13/2023 YELLOW JACKET PERF KU 12-17 50133205770000 208089 6/14/2023 YELLOW JACKET PERF MP F-89 50029232680000 205090 7/6/2023 READ Caliper Survey MP K-05 50029226700000 196068 5/30/2023 READ Caliper Survey MPU E-23 50029225700000 195094 6/23/2023 YELLOW JACKET CUT MPU L-43 50029231900000 203224 6/27/2023 YELLOW JACKET PERF PAXTON 12 50133207100000 223014 6/28/2023 YELLOW JACKET PERF Please include current contact information if different from above. T37830 T37830 T37831 T37831 T37831 T37832 T37833 T37834 T37835 T37836 T37837 YELLOWKBU 33-06X 50133205290000 203183 6/14/2023 GPT/PERFJACKET YELLOWKBU 33-06X 50133205290000 203183 6/29/2023 GPT/PERFJACKET YELLOWKBU 33-06X 50133205290000 203183 6/13/2023 PERFJACKET Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.11 14:54:56 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230422 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-26 50283200830000 212050 6/2/2023 AK E-LINE PPROF BRU 222-34 50283201860000 222039 6/14/2023 AK E-LINE Perf BRU 244-27 50283201850000 222038 6/13/2023 AK E-LINE Perf KBU 33-06X 50133205290000 203183 6/17/2023 AK E-LINE Patch Paxton 12 50133207100000 223014 6/7/2023 AK E-LINE Perf PBU 18-29C 50029223160300 209055 6/2/2023 AK E-LINE CBL Pearl 10 50133207110000 223028 6/6/2023 AK E-LINE Perf Pearl 11 50133207120000 223032 6/8/2023 AK E-LINE Perf Please include current contact information if different from above. PTD: 190-042 T37810 T37811 T37812 T37813 T37814 T37815 T37816 T37817 KBU 33-06X 50133205290000 203183 6/17/2023 AK E-LINE Patch Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.10 13:32:37 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:Fwd: KBU 33-06X (PTD# 203-183) Sundry number 323-304 patch request Date:Friday, June 16, 2023 12:29:22 PM Please include in the well file Sent from my iPhone Begin forwarded message: From: "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Date: June 16, 2023 at 12:28:20 PM AKDT To: Jacob Flora <Jake.Flora@hilcorp.com> Cc: Chad Helgeson <chelgeson@hilcorp.com>, "Ed Hawker - (C)" <Ed.Hawker@hilcorp.com>, Brady Williams <bwilliams@ake-line.com> Subject: Re: KBU 33-06X (PTD# 203-183) Sundry number 323-304 patch request Yes, Hilcorp has approval to set the patch as described below under the existing sundry. Bryan Sent from my iPhone On Jun 16, 2023, at 11:11 AM, Jacob Flora <Jake.Flora@hilcorp.com> wrote: Hi Bryan, Below is a snapshot of the WBD. Yesterday (6/15/23), we perforated an uphole sand in the Sterling Pool 4 (same pool as open perfs below) and turned out to be wet. We are requesting permission to patch the wet perfs. Procedure is to MIRU Eline PT 250L/2500H PU 35’ patch, set across wet zone at 4050’ – 4080’ RD Eline Thanks, Jake <image001.png> From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, June 16, 2023 7:47 AM To: Jacob Flora <Jake.Flora@hilcorp.com>; Daniel Yancey <dyancey@hilcorp.com>; Reid Edwards <reedwards@hilcorp.com> Subject: Fwd: KBU 33-06X (PTD# 203-183) Sundry number 323-304 patch request FYI, this is what I sent Bryan in case you need to talk with him today. Brady and Joe weren’t sure what their schedule would be, but if we can get it set this weekend that would be great. Chad Sent from my iPhone Begin forwarded message: From: Chad Helgeson <chelgeson@hilcorp.com> Date: June 15, 2023 at 11:19:00 AM AKDT To: "McLellan, Bryan J (CED)" <bryan.mclellan@alaska.gov> Cc: Noel Nocas <Noel.Nocas@hilcorp.com>, Donna Ambruz <dambruz@hilcorp.com> Subject: KBU 33-06X (PTD# 203-183) Sundry number 323- 304 patch request Bryan Today we perforated a 30ft gun of the 60 ft we proposed in the sundry and we brought in water. Previous to this perforating the zones below it were making 600mcfd of gas. I did not include a contingency in the procedure for setting a patch as we were pretty confident that the zone was dry based on offset well data. We were incorrect in that assumption. Can we have approval to set a permanent X-Span Eline patch across 4050-4080 interval. It will be a 35-40ft long patch. Procedure is to MIRU Eline PT 250L/2500H PU patch, RIH and set across zone RD Eline If fluid level is high enough, may still need to unload with N2 which already had a contingency in it. Let me know if you need more info or need me to submit some different info for this approval. Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination,distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibilityof the recipient to ensure that the onward transmission, opening, or use of this message and anyattachments will not adversely affect its systems or data. No responsibility is accepted by thecompany in this regard and the recipient should carry out such virus and other checks as it considersappropriate. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,405'NA Casing Collapse Structural Conductor 1,500psi Surface 1,950psi Intermediate 4,750psi Production 10,530psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: NA NA June 5, 2023 NA NA See Schematic See Schematic NA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 203-183 50-133-20529-00-00 Kenai Gas Field STERLING 4 GAS Same CO 510B Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 33-06X Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 7,844'5,980'5,459'~1110psi 5,980' MD 6,870psi 3,060psi 3,450psi 139' 1512' 5,246' 139' 1512' 5,752' Perforation Depth MD (ft): 8,341'3-1/2" 9-5/8"5,731' 20" 13-3/8" 118' 1,491' 10,160psi7,801'8,362' m n P s t _ 66 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-304 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.05.23 15:32:57 - 08'00' Noel Nocas (4361) DSR-5/24/23SFD 5/27/2023 10-404 BJM 6/5/23 Include results of post-perf MITIA in the 10-404 SFD GCW 06/05/2023JLC 6/5/2023 06/05/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.05 14:24:56 -08'00' RBDMS JSB 060623 Well: KBU 33-06X Date: 5/22/23 PTD: 203-183 Well Name: KBU 33-06X API Number: 50-133-20529-00-00 Current Status: Flowing Gas Well Permit to Drill Number: 203-183 First Call Engineer: Chad Helgeson (907) 777-8405 (o) (907) 229-4824 (c) Second Call Engineer: Jake Flora (907) 777-8503 (o) (907) 301-1736 (c) Maximum Expected BHP: 1,465 psi @ 3,552’ TVD Based on KU 11-07X RFT data on 4/2017 Maximum Potential Surface Pressure: ~1110 psi @ 3,552’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Well Summary KBU 33-06X was drilled in the Kenai Gas Field in January 2004. It was completed with a 3.5” EXCAPE completion string to 8,405’. The Beluga sands were plugged back in 2021 and it was converted to a Pool 6 gas storage well in fall of 2021. The C2 sand was perforated and had no flow from Pool 6 storage sand. In 2022 a cement annulus was pumped to isolate the Sterling Sands, and perforated in Sterling Pool 4 successfully. The well has been online flowing from Pool 4 for 11 months. There is additional Pool 4 sand to be perforated in the well. Notes Regarding Wellbore Condition x Original Cement Bond Log Cement top @ 4,750’ x Secondary Cement Bond Log post cement annulus squeeze @ 2,825’ x Max Inclination = 36.5 degrees at 3,625’ MD x MIT-IA to 2,000 psi on 6/29/22 x EXCAPE control lines squeezed 9/19/21 Notes Regarding Wellbore Condition x Recent history o 5/16/23 – SL tagged obstruction at 4,050’ (possibly dry soap sticks) E-Line procedure 1. MIRU SL and PCE, PT Lubricator to 250L/ 2500 H 2. Bail fill/Cleanout well from with well flowing to 4,100’ 3. RD SL 4. MIRU E-line and PCE, PT lubricator 250L/ 2500 H 5. RIH and perforate Sterling Pool 4 B1U sands from ±4,020’ – ±4,080’ (60ft) MD per RE/Geo a. Proposed perfs. also shown on the proposed schematic in red font. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. c. Use Gamma/CCL to correlate. d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals post shot. e. This sand is in the Kenai Sterling Gas Pool 4 per CO 510B. 6. Turn well over to operations and flow the well. Post-Perf MIT-IA Well: KBU 33-06X Date: 5/22/23 PTD: 203-183 Perform MIT-IA to 2000psi once job is complete and well has been brought online within 30 days. Contingency CT Procedure – In the event SL cannot clean well deep enough – Preperf 1. MIRU CTU, 24hr notice for BOP test to AOGCC 2. Conduct BOP test to 250psi Low / 3500psi High 3. Clean out well with N2/foam to 4100’ 4. Unload with n2 after cleanout is complete 5. RDMO CT Attachments: 1. Current schematic 2. Proposed Schematic 3. CT BOP Schematic (Fox) 4. Standard Well procedure – N2 Operations Perform MIT-IA to 2000psi once job is complete and well has been brought online within 30 days. TOC @ 2,825' CBL 6/22/2022 TOC @ 4259' 6/22/22 Tubing punch 4400'-4403 6/18/22 5,025' CIBP w 28' cmt 6/18/22 6005' CIBP w 25' cmt top (9/18/21) TD 8,405' MD 7,840' TVD Perforations: Sterling P4_B1 4,087'-4,093' 2-3/8 5spf 6/26/22Sterling P4_B2U 4,119'-4,134' 2-3/8 5spf 6/26/22Sterling P4_B2L 4,150'-4,156' 2-3/8 5 spf 6/26/22 Sterling C2 5045-5077' 2-3/8 6spf (9/24/21) - Plugged Control lines: Red 1/4" control line: squeezed 1.5 gal cmt (9/19/21)Yellow 1/4" control line: squeezed 1.5 gal cmt (9/19/21)Green 1/4" control line: squeezed 1.5 gal cmt (9/19/21) Excape Mod Perfs MD (RKB):Module 20 - 6,119'- 6,129'Module 19 - 6,196'- 6,206'Module 18 - 6,279'- 6,289'Module 17 - 6,444'- 6,454'Module 16 - 6,543'- 6,553'Module 15 - 6,681'- 6,691'Module 14 - 6,724'- 6,734'Module 13 - 6,781'- 6,791'Module 12 - 6,858'- 6,868'Module 11 - 7,084'- 7,094'Module 10 - 7,122'- 7,132'Module 9 - 7,169'- 7,179'Module 8 - 7,240'- 7,250'Module 7 - 7,301'- 7,311'Module 6 - 7,379'- 7,389'Module 5 - 7,505'- 7,515'Module 4 - 7,791'- 7,801'Module 3 - 7,967'- 7,977' Module 2 - 8,102'- 8,112'Module 1 - 8,197'- 8,207' 3-1/2" x 9-5/8" TOC: 4750' MD (1/22/04 CBL) Excape System Details * BHP monitoring line volume tank located from 6,055' - 6,093' KBU 33-6X Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. Permit #:203-183 API #:50-133-20529-00-00 Prop. Des:FED A - 028142 KB Elevation:82' (21' AGL) Latitude: Longitude: Spud:12/13/2003 TD:1/2/2004 PBTD 4,259' MD 3,968' TVD Drive Pipe20" K-55 133 ppf PE Top BottomMD 0' 139' TVD 0' 139' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,512'TVD 0' 1,512' Cmt w/ 320 sks Intermediate Casing 9-5/8" L-80 47 ppf BTC Top BottomMD 0' 5,752' TVD 0' 5,246' Cmt w/ 705 sks Class G in 12.25" OH. Volumetric ToC estimate: 3053' with 50% washout, 1704' with no washout Production Tubing3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rdMD 0' 8,362' TVD 0' 7,800' Cmt w/ 1,150 sks of class G cmt Tag fill @: * 7,994' w/ Dynacoil (5/27/2010) * 7,876' w/ Dynacoil (3/2/2010) * 7,915' w/ Dynacoil (5/12/2009) Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 33-6x Kenai Peninsula Borough 4,087' - 8,207' 1.3º / 100 ft @ 1,500' 1/9/2004Donna Ambruz Lease: State: Perf (TVD): Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 3,928' - 7,647' 8º ĺ 5.5º RKB:(AMSL)21' (AGL) 7/12/2022 Slickline tag w/ 2-1/4" LIB. Indicated "pinched in" pipe @ 7534' kb. 2-1/2" bailer got stuck @ 6127' kb. (4/19/12) 9-5/8" x 12.25" TOC: 3053' MD (Vol estimate with 50% washout) 5752' 9-5/8 CSG * MITIA to 1500 psi Passed 9/19/21 5045-5077' C2 perfs P4 TOC @ 2,825' CBL 6/22/2022 TOC @ 4259' 6/22/22 Tubing punch 4400'-4403 6/18/22 5,025' CIBP w 28' cmt 6/18/22 6005' CIBP w 25' cmt top (9/18/21) TD 8,405' MD 7,840' TVD Perforations: Sterling P4_B1U ±4,020'-4,080' 2" 6spf Sterling P4_B1 4,087'-4,093' 2-3/8 5spf 6/26/22Sterling P4_B2U 4,119'-4,134' 2-3/8 5spf 6/26/22Sterling P4_B2L 4,150'-4,156' 2-3/8 5 spf 6/26/22 Sterling C2 5045-5077' 2-3/8 6spf (9/24/21) - Plugged Control lines: Red 1/4" control line: squeezed 1.5 gal cmt (9/19/21)Yellow 1/4" control line: squeezed 1.5 gal cmt (9/19/21)Green 1/4" control line: squeezed 1.5 gal cmt (9/19/21) Excape Mod Perfs MD (RKB):Module 20 - 6,119'- 6,129'Module 19 - 6,196'- 6,206'Module 18 - 6,279'- 6,289'Module 17 - 6,444'- 6,454'Module 16 - 6,543'- 6,553'Module 15 - 6,681'- 6,691'Module 14 - 6,724'- 6,734'Module 13 - 6,781'- 6,791'Module 12 - 6,858'- 6,868'Module 11 - 7,084'- 7,094'Module 10 - 7,122'- 7,132'Module 9 - 7,169'- 7,179'Module 8 - 7,240'- 7,250'Module 7 - 7,301'- 7,311'Module 6 - 7,379'- 7,389'Module 5 - 7,505'- 7,515'Module 4 - 7,791'- 7,801'Module 3 - 7,967'- 7,977' Module 2 - 8,102'- 8,112' 3-1/2" x 9-5/8" TOC: 4750' MD (1/22/04 CBL) Excape System Details * BHP monitoring line volume tank located from 6,055' - 6,093' KBU 33-6X Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. Permit #:203-183 API #:50-133-20529-00-00 Prop. Des:FED A - 028142 KB Elevation:82' (21' AGL) Latitude: Longitude: Spud:12/13/2003 TD:1/2/2004 PBTD 4,259' MD 3,968' TVD Drive Pipe20" K-55 133 ppf PE Top BottomMD 0' 139' TVD 0' 139' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,512'TVD 0' 1,512' Cmt w/ 320 sks Intermediate Casing 9-5/8" L-80 47 ppf BTC Top BottomMD 0' 5,752' TVD 0' 5,246' Cmt w/ 705 sks Class G in 12.25" OH. Volumetric ToC estimate: 3053' with 50% washout, 1704' with no washout Production Tubing3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rdMD 0' 8,362' TVD 0' 7,800' Cmt w/ 1,150 sks of class G cmt Tag fill @: * 7,994' w/ Dynacoil (5/27/2010) * 7,876' w/ Dynacoil (3/2/2010) * 7,915' w/ Dynacoil (5/12/2009) Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 33-6x Kenai Peninsula Borough 4,087' - 8,207' 1.3º / 100 ft @ 1,500' 1/9/2004 C Helgeson Lease: State: Perf (TVD): Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 3,928' - 7,647' 8º ĺ 5.5º RKB:(AMSL)21' (AGL) 5/22/2023 Slickline tag w/ 2-1/4" LIB. Indicated "pinched in" pipe @ 7534' kb. 2-1/2" bailer got stuck @ 6127' kb. (4/19/12) 9-5/8" x 12.25" TOC: 3053' MD (Vol estimate with 50% washout) 5752' 9-5/8 CSG * MITIA to 1500 psi Passed 9/19/21 5045-5077' C2 perfs P4 P4 PROPOSED STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Noel Nocas Subject:RE: KBU 33-06X (PTD# 203-183) Sundry # 323-304 perf Adds Date:Tuesday, June 6, 2023 4:50:00 PM Chad, Hilcorp has approval to reperforate the zones listed below as part of sundry 323-304. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, June 6, 2023 4:17 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com> Subject: KBU 33-06X (PTD# 203-183) Sundry # 323-304 perf Adds Bryan Hilcorp received the Sundry approval (#323-304) for well KBU 33-06X at Kenai Gas Field (PTD# 203- 183) and as we discussed on the phone we would like to add reperforate the existing sands that are flowing to increase the shot density. Currently the zones are perforated at 5 spf and we would like to increase this to 11 spf. Below are the proposed perf depths that are the same as what is already perforated. Sand Depth Depth bottom Current Status Sterling Pool 4 4,087’4,093’Open Sterling Pool 4 4,119’4,134’Open Sterling Pool 4 4,150’4,156’Open Please let us know if we have approval to add these perfs to existing Sundry # 323-304, or send me a note to let me know if you need anything else. Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221128-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# CLU 13 50133206460000 214171 11/12/2022 Halliburton PERF CLU 05RD2 50133204740200 222092 11/11/2022 Halliburton PPROF KBU 22-06 50133205500000 205054 2/26/2022 Halliburton RMX KBU 22-06 50133205500000 205054 2/26/2022 Halliburton TMD3D KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton RMX KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton TMD3D KDU 4 50133201760000 169012 11/7/2022 Halliburton EPX KDU 4 50133201760000 169012 11/7/2022 Halliburton MFC24 KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton EPX KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton MFC24 Please include current contact information if different from above. By Meredith Guhl at 10:05 am, Nov 29, 2022 T37319 T37313 T37320 T37320 T37321 T37321 T37322 T37322 T37323 T37323 KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton RMX KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton TMD3D Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 11:15:51 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SRU 213-15 50133206520000 215100 6/24/2022 Yellowjacket PERF KBU 33-06X 50133205290000 203183 6/26/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 6/28/2022 Yellowjacket GPT-PERF END 3-17F 50029219460600 203216 7/2/2022 Yellowjacket PERF-RETAINER KBU 32-08 50133206240000 214014 7/12/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 7/15/2022 Yellowjacket GPT-PERF SRU 213-15 50133206520000 215100 7/19/2022 Yellowjacket GPT-PLUG MPU I-17 50029232120000 204098 7/19/2022 Yellowjacket TUBING CUT CLU 05RD 50133204740100 215160 7/21/2022 Yellowjacket PLUG CLU 10 50133205530000 205106 7/21/2022 Yellowjacket RCT-JET CUT SRU 213-15 50133206520000 215100 7/22/2022 Yellowjacket PERF Please include current contact information if different from above. By Meredith Guhl at 8:52 am, Nov 23, 2022 T37295 T37295 T37295 T37296 T37297 T37297 T37298 T37299 T37300 T37301 T37302 KBU 33-06X 50133205290000 203183 6/26/2022 Yellowjacket PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.23 09:08:15 -09'00' Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes AOGCC Eset # BRU 212-24 50283200370000 172015 7/27/2022 AK E-Line CIBP BRU 233-27 50283100260000 163002 7/2/2022 AK E-Line PERF HVA B-16 50231200400000 212133 6/23/2022 AK E-Line PLUG/CEMENT KBU 11-08Z 50133206290000 214044 6/22/2022 AK E-Line PERF KBU 33-06X 50133205290000 203183 6/18/2022 AK E-Line PLUG/CEMENT/PUNCH MPU I-17 50029232120000 204098 7/9/2022 Read CALIPER SRU 32A-33 50133101640100 191014 6/20/2022 Halliburton TMD3D-WFL + Report Please include current contact information if different from above. T36794 T36795 T36796 T36797 T36798 T36799 T36800 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.19 09:04:04 -08'00' By Samantha Carlisle at 12:37 pm, Jul 15, 2022 Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -08'00' 7\SHRI5HTXHVW$EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 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3HUIRUDWLRQ'HSWK0'IW 6HH$WWDFKHG6FKHPDWLF 6HH$WWDFKHG6FKHPDWLF -XQH 1$ 1$1$ 3 W VV )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 1:25 pm, Jun 03, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH %-0 ; 6)' 3URYLGH KUV QRWLFH IRU $2*&& WR ZLWQHVV WDJSUHVVXUH WHVW RI FHPHQW SOXJ 3HUIRUDWH1HZ3 RRO3 '65 6XEPLW &%/ ORJ WR $2*&& IRU DSSURYDO WR SHUIRUDWH 0,7,$ WR DW OHDVW SVL DIWHU SXWWLQJ ZHOO RQ SURGXFWLRQ ZLWKLQ GD\V -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.08 13:21:03 -08'00' RBDMS JSB 062922 tĞůů͗<hϯϯͲϬϲy ĂƚĞ͗ϲͲϮͲϮϮ Wd͗ϮϬϯͲϭϴϯ tĞůůEĂŵĞ͗<hϯϯͲϬϲyW/EƵŵďĞƌ͗ϱϬͲϭϯϯͲϮϬϱϮϵͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/'ĂƐ^ƚŽƌĂŐĞtĞůů>ĞŐ͗Eͬ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌϳϳϳͲϴϯϬϱWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϯͲϭϴϯ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;ŽͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;ĐͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ;ϵϬϳͿϳϳϳͲϴϱϬϯ;ŽͿ;ϵϬϳͿϯϬϭͲϭϳϯϲ;ĐͿ Maximum Expected BHP: 1,465 psi @ 3,552’ TVD Based on KU 11-07X RFT data on 4/2017 Maximum Potential Surface 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different from above. 203-183 T36452 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.04.08 08:30:38 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/09/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 33-06X (PTD 203-183) GPT/PERF 09/30/2021 Please include current contact information if different from above. 37' (6HW By Abby Bell at 4:45 pm, Nov 09, 2021 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/20/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 33-06X (PTD 203-183) Completion Record Perf 09/24/2021 Please include current contact information if different from above. 37' (6HW Received By: d 10/25/2021 By Abby Bell at 12:29 pm, Oct 25, 2021 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 33-6X (PTD 203-183) Plug 09/18/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/19/2021 By Abby Bell at 12:48 pm, Oct 19, 2021 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,405'NA Casing Collapse Structural Conductor 1,500psi Surface 1,950psi Intermediate 4,750psi Production 10,530psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: September 18, 2021 NA 8,362' Perforation Depth MD (ft): 5,752' See Attached Schematic 8,341'7,801'3-1/2" 20" 13-3/8" 118' 9-5/8"5,731' 1,491' 3,060psi 3,450psi 139' 1512' 5,246' 139' 1512' NA TVD Burst NA 10,160psi MD 6,870psi Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 203-183 50-133-20529-00-00 KBU 33-06X Kenai Gas Field / Pool 6 Sterling COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic jake.flora@hilcorp.com 7,844'8,324'7,763'200 psi NA NA NA Perforation Depth TVD (ft):Tubing Size: m n P 66 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:47 am, Sep 08, 2021 321-455 ManagerManagerDigitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.07 16:31:24 -08'00' Taylor Wellman (2143) SFD 9/10/2021 SFD 9/8/2021 DSR-9/8/21 10-404 SFD 9/10/2021 Pool 6 Sterling SFD 9/8/2021FEDA028142 BJM 9/10/21 Perforate New Pool P CO 510B dts 9/12/2021 JLC 9/13/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.13 10:03:25 -08'00' RBDMS HEW 9/13/2021 Well Prognosis Well: KBU 33-06X Date: 09/03/21 Well Name: KBU 33-06X API Number: 50-133-20529-00-00 Current Status: Gas Producer Leg: NA Estimated Start Date: 9/18/21 Rig: NA Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 203-183 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (985) 632-4113 (C) AFE Number: Current Bottom Hole Pressure: 200 psi @ 5,235’ TVD Based on actual reservoir conditions. Max. Potential Surface Pressure: 200 psi Well Status KBU 33-06X is a SI producer. Brief Well Summary The purpose of this work/sundry is to convert the SI ‘Excape’ well to a Pool 6 producer. Notes Regarding Wellbore Condition Procedure: 1. MITIA to 1500 psi. 2. RU E-line, PT Lubricator to 3000 psi. 3. Set CIBP at ~6000’, dump bail 25’ cement on plug. 4. Swab well dry. 5. Perforate Pool 6 interval below: Sterling C1 4835’-5000’ MD (4441’ to 4579’ TVD) Sterling C2 5045’ to 5077’ MD (4617’ to 4644’ TVD) 6. MITIA to 1500 psi. 7. Squeeze Excape control lines. Attachments 1. Current Well Schematic 2. Proposed Well Schematic Squeeze control lines before perforating if possible to inject. If unable to inject cement into lines before perforating, make a second attempt after perforating. BJM to a Pool 6 producer. Set CIBP as close as possible to top perf above Excape completion equipment in attempt to meet requirement in 20 AAC 25.112.(c)(1)(E) of placing plug <50' above perf. bjm o convert t TD 8,405' MD 7,840' TVD Perforations: Excape Mod Perfs MD (RKB):Module 20 -6,119'-6,129'p(p( Module 19 - 6,196'- 6,206'Module 18 - 6,279'- 6,289'Module 17 - 6,444'- 6,454'Module 16 - 6,543'- 6,553'Module 15 - 6,681'- 6,691'Module 14 - 6,724'- 6,734'Module 13 - 6,781'- 6,791'Module 12 - 6,858'- 6,868'Module 11 - 7,084'- 7,094'Module 10 - 7,122'- 7,132'Module 9 - 7,169'- 7,179'Module 8 - 7,240'- 7,250'Module 7 - 7,301'- 7,311'Module 6 - 7,379'- 7,389'Module 5 - 7,505'- 7,515'Module 4 - 7,791'- 7,801'Module 3 - 7,967'- 7,977' Module 2 - 8,102'- 8,112' 3-1/2" x 9-5/8" TOC: 4750' MD (1/22/04 CBL) Excape System Details * BHP monitoring line volume tank located from 6,055' - 6,093' KBU 33-6x Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. Permit #:203-183 API #:50-133-20529-00-00 Prop. Des:FED A -028142 KB Elevation:82' (21' AGL) Latitude: Longitude: Spud:12/13/2003 TD:1/2/2004 PBTD 8,324' MD 7,763' TVD Drive Pipe 20" K-55 133 ppf PE Top Bottom MD 0' 139' TVD 0' 139' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,512' TVD 0' 1,512' Cmt w/ 320 sks Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 5,752' TVD 0' 5,246' Cmt w/ 705 sks Class G in 12.25" OH. Volumetric ToC estimate: 3053' with 50% washout, 1704' with no washout Production Tubing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 8,362' TVD 0' 7,800' Cmt w/ 1,150 sks of class G cmt Tag fill @: * 7,994' w/ Dynacoil (5/27/2010) * 7,876' w/ Dynacoil (3/2/2010) * 7,915' w/ Dynacoil (5/12/2009) Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 33-6x Kenai Peninsula Borough 6,119' -8,207' 1.3º / 100 ft @ 1,500' 1/9/2004 Mike Sulley Lease: State: Perf (TVD): Kenai Gas Field y Angle @ Perfs: Ground Level: Revision Date: Alaska USACountry: 5,591' -7,647' 8º ĺ 5.5º (AMSL) 21' (AGL)RKB: 4/23/2012 Slickline tag w/ 2-1/4" LIB. Indicated "pinched in" pipe @ 7534' kb. 2-1/2" bailer got stuck @ 6127' kb. (4/19/12) 9-5/8" x 12.25" TOC: 3053' MD (Vol estimate with 50% washout) 5752' 9-5/8 CSG PROPOSED 4830-4930' Pool 6 Perfs (proposed) ~6000' CIBP w cmt top (proposed) TD 8,405' MD 7,840' TVD Perforations: Excape Mod Perfs MD (RKB):Module 20 -6,119'-6,129'p(p( Module 19 - 6,196'- 6,206'Module 18 - 6,279'- 6,289'Module 17 - 6,444'- 6,454'Module 16 - 6,543'- 6,553'Module 15 - 6,681'- 6,691'Module 14 - 6,724'- 6,734'Module 13 - 6,781'- 6,791'Module 12 - 6,858'- 6,868'Module 11 - 7,084'- 7,094'Module 10 - 7,122'- 7,132'Module 9 - 7,169'- 7,179'Module 8 - 7,240'- 7,250'Module 7 - 7,301'- 7,311'Module 6 - 7,379'- 7,389'Module 5 - 7,505'- 7,515'Module 4 - 7,791'- 7,801'Module 3 - 7,967'- 7,977' Module 2 - 8,102'- 8,112' 3-1/2" x 9-5/8" TOC: 4750' MD (1/22/04 CBL) Excape System Details * BHP monitoring line volume tank located from 6,055' - 6,093' KBU 33-6x Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. Permit #:203-183 API #:50-133-20529-00-00 Prop. Des:FED A -028142 KB Elevation:82' (21' AGL) Latitude: Longitude: Spud:12/13/2003 TD:1/2/2004 PBTD 8,324' MD 7,763' TVD Drive Pipe 20" K-55 133 ppf PE Top Bottom MD 0' 139' TVD 0' 139' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,512' TVD 0' 1,512' Cmt w/ 320 sks Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 5,752' TVD 0' 5,246' Cmt w/ 705 sks Class G in 12.25" OH. Volumetric ToC estimate: 3053' with 50% washout, 1704' with no washout Production Tubing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 8,362' TVD 0' 7,800' Cmt w/ 1,150 sks of class G cmt Tag fill @: * 7,994' w/ Dynacoil (5/27/2010) * 7,876' w/ Dynacoil (3/2/2010) * 7,915' w/ Dynacoil (5/12/2009) Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Beluga Unit 33-6x Kenai Peninsula Borough 6,119' -8,207' 1.3º / 100 ft @ 1,500' 1/9/2004 Mike Sulley Lease: State: Perf (TVD): Kenai Gas Field y Angle @ Perfs: Ground Level: Revision Date: Alaska USACountry: 5,591' -7,647' 8º ĺ 5.5º (AMSL) 21' (AGL)RKB: 4/23/2012 Slickline tag w/ 2-1/4" LIB. Indicated "pinched in" pipe @ 7534' kb. 2-1/2" bailer got stuck @ 6127' kb. (4/19/12) 9-5/8" x 12.25" TOC: 3053' MD (Vol estimate with 50% washout) 5752' 9-5/8 CSG SFD 9/8/2021 Isolated perfs in the Beluga/Upper Tyonek Gas Pool Pool 6 depths in KBU 33-06X C1 - 4835'-5000' MD (4441' to 4579' TVD) C2 - 5045' to 5077' MD (4617' to 4644' TVD) per J. Flora, Hilcorp, email dated 9/8/2021 SFD 9/8/2021 1 Guhl, Meredith D (CED) From:Davies, Stephen F (CED) Sent:Friday, September 10, 2021 12:53 PM To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] KBU 33-06X (PTD 203-183; Sundry 321-455) - Question Please file this email thread instead of the previous email. Thanks, Steve From: Davies, Stephen F (CED) Sent: Friday, September 10, 2021 12:47 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Cc: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; Roby, David S (CED) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] KBU 33‐06X (PTD 203‐183; Sundry 321‐455) ‐ Question Jake, KBU 33‐06X will be classified as a gas production well that is governed by Conservation Order 510B. It would be classified as a gas storage well if Hilcorp planned to inject gas into it, and then the requirements of Storage Injection Order 7A would apply. Bryan and I have made the appropriate corrections to Hilcorp’s application form. Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907‐793‐1224 or steve.davies@alaska.gov. From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Friday, September 10, 2021 11:45 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; Roby, David S (CED) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] KBY 33‐06X (PTD 203‐183; Sundry 321‐455) ‐ Question Steve, This would be a producer only. thanks From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Friday, September 10, 2021 11:36 AM To: Jacob Flora <Jake.Flora@hilcorp.com> 2 Cc: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; Roby, David S (CED) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] KBY 33‐06X (PTD 203‐183; Sundry 321‐455) ‐ Question Jake, Does Hilcorp intend to inject gas into this well, or just produce from it? Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907‐793‐1224 or steve.davies@alaska.gov. From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Friday, September 10, 2021 11:06 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; Roby, David S (CED) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] KBY 33‐06X (PTD 203‐183; Sundry 321‐455) ‐ Question Hi Steve, My interpretation was that a Pool 6 well of any type would be a gas storage well, which code is the correct for a case like this? Please adjust as needed thanks, Jake From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Friday, September 10, 2021 10:49 AM To: Jacob Flora <Jake.Flora@hilcorp.com> Cc: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; Roby, David S (CED) <dave.roby@alaska.gov> Subject: [EXTERNAL] KBY 33‐06X (PTD 203‐183; Sundry 321‐455) ‐ Question Hi Jake, For the KBU 33‐06X well, the boxes on the Sundry Application form describing the well class and status after the proposed work are checked “Development” and “GSTOR.” Hilcorp’s Brief Well Summary indicates the well will be a Pool 6 producer. I’m assuming that the well will NOT be used as a gas storage well, and that the check in the GSTOR box is an error. Am I correct? Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907‐793‐1224 or steve.davies@alaska.gov. 3 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Davies, Stephen F (CED) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] KBU 33-06X (PTD 203-183; Sundry 321-455) - Question Date:Wednesday, September 8, 2021 2:10:53 PM Please file. Thanks. From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Wednesday, September 8, 2021 2:02 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Roby, David S (CED) <dave.roby@alaska.gov>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] KBU 33-06X (PTD 203-183; Sundry 321-455) - Question Hello Steve, The correct Pool 6 depths are the ones in the Sundry procedure and NOT the ones on the wellbore diagram. I apologize for the discrepancy, Jake Pool 6 depths in KBU 33-06X C1 – 4835’-5000’ MD (4441’ to 4579’ TVD) C2 – 5045’ to 5077’ MD (4617’ to 4644’ TVD) From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Wednesday, September 8, 2021 12:01 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Cc: Roby, David S (CED) <dave.roby@alaska.gov>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL] KBU 33-06X (PTD 203-183; Sundry 321-455) - Question Jake, In this Sundry Application, the proposed perforation footages for Sterling C1 and C2 listed on page 1 don’t match the perforations annotated on the proposed wellbore schematic drawing. Which are correct? Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 RECEIVED Anchorage,AK 99503 Phone:907/777-8380012 Fax May 28, 2014 MAY 2 8 2014 JO - I 3 AOGCC Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Expansion of Coiled Tubing Work at Ninilchik Unit and Kenai Gas Field Dear Commissioner Foerster: Attached for your information are additional wells that Hilcorp AK has identified that require coiled tubing operations but do not require sundry approval. The wells listed below in bold print are in addition to the original wells requested in our letters dated May 7, 2014 and February 12, 2014 (attached). Our company supervision will give notice during the initial rig up of the Coiled Tubing BOPE for the initial BOPE test. Below is a list of the wells and the proposed coiled tubing work: SD-07 (PTD 211-050) Fill Cleanout+Ad Perfs SD-08 (PTD 213-051) Fill Cleanout+Blow well down SD-02A (PTD 213-153) Fill Cleanout KBU 11-08Z (PTD 214-044) Blow well down KBU 33-6X (PTD 203-183) Fill Cleanout If you need any additional information, you can contact me at 907-777-8333. Sincerely, HILCORP ALASKA, OP SCANNED SEP 2 2201c Paul Chan Senior Operations Engineer pc Attachments ECOPY . Permit#: 203-183 API#: 50-133-2.0529-00-00 KBU 33-6x 111 Prop.Des: FED A-028142 Pad 41-7 KB Elevation: 82'(21'AGL) 42' FSL, 860' FEL, Iiil.mrn Alaska-LLC Latitude: Drive Pipe Longitude: Sec. 6, T4N, R11 W, S.M. 20" K-55 133 ppf PE Spud: 12/13/2003 Top Bottom MD 0' 139' TD: 1/2/2004 _ _ TVD 0' 139' Rig Released: Surface Casing 13-3/8" K-55 68 ppf BTC h - Top Bottom � _,� MD 0' 1,512' 11, TVD 0' 1,512' .. Cmt w/320 sks TOC(est.)-???' r' Intermediate Casing Excape System Details �• ! 9-5/8" L-80 47 ppf BTC ., +a Top Bottom 'BHP monitoring line volume tank MD o' 5,752' I_located from 6,055'-6,093' TVD 0' 5,246' Cmt w/705 sks Class G 111 •. Production Tubing Excape System Details I 3-1/2" L-80 9.3 ppf Mod EUE 20 Conventional modules Top Bottom 8rd Module 1-no flapper valve -Ceramic flapper valves below N • MD 0' 8,362' each module as follows: I �` ND 0' 7,800' 4: 4 Cmt w/1,150 sks of class G cmt Fla.pers MD(RKB): ii Module 20 6,138' Module 19 - 6,215' "r ._ q (Org.Install Module 18 - 6,298' 4 I Capillary Stria 07/03/08) Module 17 - 6,463' s: , 3/8" 2205 Stainless Steel Module 16 - 6,562' Top Bottom Module 15 - 6,700' , MD 0' 6,119' Module 14 - 6,743' TVD 0' 5,591' Module 13 - 6,800' I Replaced BHA. Set @ 3000 psi (4/20/121 Module 12 - 6,879' Module 11 - 7.103' I Module 11 - 7,103' b K Beluga/Tyonek Excape Details Module 10 - 7,141' g I -20 Excape modules placed Module 9 - 7,188 ' Module 8 - 7,259 - control line fires top 9 modules Module 7 - 7.320 8 modules tol line fires middle Module 6 - 7,398' -Green control line fires bottom Module 5 - 7,524' ! 3 modules Module 4 - 7,812' a t Ceramic flapper valves below each Module 2 - 8,121 . Module 1 - iIA , Perfs MD(RKB): Module 2 - 6,119'-6,129' Module 19 - 6,196'-6,206' Module 18 - 6,279'-6,289' Module 17 - 6,444'-6,454' Module 16 - 6,543'-6,553' Module 15 - 6,681'-6,691' : Module 14 - 6,724'-6,734' 1,7"' Module 13 - 6,781'-6,791' v Module 12 - 6,858'-6,868' i Module 11 - 7,084'-7,094' Module 10 - 7,122'-7,132' Module 9 - 7,169'-7,179' '" Module 8 - 7,30'-'-7,3111' 'a '' Module 6 - 7,379'-7,389' Module 5 - 7,505'-7,515' :it., Module 4 - 7,791'-7,801' Slickline tag w/2.1/4'LIB. Module 3 - 7,967'-7,977 Indicated"pinched in"pipe @ • l Module 1 - 8,197'-8,207' 7534'kb 2-1/2"bailer got stuck @ 6127'kb.(4/19/12) ` • • i Tag fill(60: yt '7,994'w/Dynacoil(5/27/2010) '# t '7,876'w/Dynacoil(3/2/2010) k' t,' '7,915'w/Dynacoil(5/12/2009) I+` TD PBTD 8,405' MD 8,324' MD 7,840' TVD 7,763' TVD Well Name& Number: Kenai Beluga Unit 33-6x Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 6,119' -8,207' Perf(TVD): 5,591'-7,647' Angle © KOP& Depth: 1.3°/100 ft @ 1,500' Angle @ Perfs: 8°--. 5.5° Date Completed: 1/9/2004 Ground Level: (AMSL) RKB: 21' (AGL) Revised by: Mike Sulley Revision Date: 4/23/2012 • Kenai Gas Field Well: KBU 11-08Z SCHEMATIC Last Completed: FUTURE ltilcoru Alaska,t,t C PTD: 214-044 CASING DETAIL. RKB:MSL=22.2' Size Type Wt/Grade/Conn ID Top Btm , t 16" Conductor N/A Surf 130' ` 10-3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,603' 7-5/8" Intermediate 29.7/L-80/BTC Mod 6.875 Surf 5,932' 16" l 5" Production 18/L-80/DWC/C-HT 6.184 Surf 9,888' I w JEWELRY DETAIL s _ �; el No Depth Item 10-3/4"* 1 5,424' 5"Swell PackerPacker 2 7,142' RA Marker with 5'Pup 3 7,473' RA Marker with 5'Pup 4 8,004' RA Marker with 5'Pup i ttt; OPEN HOLE/CEMENT DETAIL C• r 10-3/4"" 164BBL's of cement in 13.5"Hole.Returns to Surface it 7-5/8" 220BBL's of cement in 9-7/8"Hole.TOC Est.900' }� 5" 175BBL's of cement in 6-3/4"Hole. TOC Est.1,488' F 1" II t 1 e.c.' * e t `1 7-5/8" L V. 41 t * r ,,,,it i,, '7 f 4 'N ti: 3 A SP y114 k TD=9,90(Y(MD)/9,508'(TVD) PBTD=9,800'(MD)/9,409'(TVD) Created By:TDF 5/28/2014 Hilcorp Alaska,LLC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpolnt Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8412 Fax:907/777-8310 May 7, 2014 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 W. 711' Avenue, Suite 100 Anchorage, AK 99501 Re: Coiled Tubing Work at Ninilchik Unit Dear Commissioner Foerster: Attached for your review includes proposed Coiled Tubing work for the Ninilchik Unit. IIilcorp AK is submitting a sundry application for the coiled tubing fill cleanouts with nitrogen along with additional perforations in the SD-07 well. We will also be performing CT FCO and/or blow downs on the other listed wells. Our company supervision will give notice during the initial rig up of the Coiled Tubing BOPE for the initial BOPE test. Below is a list of the wells and the proposed coiled tubing work: SD-07 (PTD 211-050) Fill Cleanout+Ad Perfs SD-08 (PTD 213-051) Fill Cleanout+Blow well down SD-02A (PTD 213-153) Fill Cleanout If you need any additional information, you can contact me at 907-777-8333. Sincerely, HILCORP ALASKA, LLC Paul Chan Operations Engineer pc • Attachments Hiicorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Phone: 907/777-8412 Fax:907/777-8310 February 12, 2014 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 W. 7°i Avenue, Suite 100 Anchorage, AK 99501 Re: Coiled Tubing Work at Kenai Gas Field Dear Commissioner Foerster: Attached for your review includes proposed Coiled Tubing work for the Kenai Gas Field. The coiled tubing work involves fill cleanouts with nitrogen. This work typically does not require sundry approval; however we are including a sundry application for the initial work proposed on Kenai Gas KBU 23-7 (PTD 203-217) to perform a fill cleanout on the well. Our company supervision will give notice during the initial rig up of the Coiled Tubing BOPE for the initial BOPE test. Below is a list of the wells and the proposed coiled tubing work: KBU 23-7 (PTD 203-217) Fill Cleanout KBU 24-6RD (PTD 206-013) Fill Cleanout KBU 34-6 (PTD 207-064) Fill Cleanout KBU 42-6 (PTD 204-209) Fill Cleanout Sundries for wells which may require a velocity string will be submitted individually. The two identified velocity string wells at this time are KTU 32-7 (PTD 200-023) and CLU-RDI (PTD 203-129). if you need any additional information,you may contact me at 907-777-8333. Sincerely, HILCORP ALASKA, LLC Paul Chan Cat....„." Operations Enginee pc Attachments McMains, Stephen E (DOA c: From: Skiba, Kevin J. (kskiba@marathonoil.com] ~~-;~- Sent: Thursday, August 26, 2010 11:48 AM To: McMains, Stephen E (DOA) Subject: Corrected Lease Numbers pZ~~f ~ ~~ Steve, After having discussion with representatives from the BLM, it was determined that the correct Lease # for KBU 33-06x &KBU 43-07x is FED A-028142. I have updated my database to reflect this correction. Thanks again for all of your help, Kevin Skiba Regulatory Compliance Representative ~~~ ~.~~ ~~pn~s Marathon Alaska Production LLC Office (907) 283-1371 Cell (907) 394-1880 Fax (907) 283-1350 RBDMS AUG ~ g ~ ~ ~,~j1'~ )`~~i~~ .' ~a i Marathon MARATHON Alaska Praductian LLC Marathon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 June 15, 2010 , ~~Ua~ :~ ~ 2~fi[, Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 aD~ _ ~ ~.~ Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Beluga Unit 33-6x Dear Mr. Aubert: Attached for your records is the10-404 Report of Sundry Well Operations for KBU 33-6x well. This report covers the work performed to raise the 3/8" capillary string up-hole to a new setting depth of 6,119' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Capillary String Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Depth Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ Ad'ustment 2. Operator 4. Well Class Before Work: .Permit to Drill Number: Name: Marathon Alaska Production LLC Development ~ Exploratory^ 203-183 3. Address: PO Box 1949 Stratigraphic ^ Service ^ ~ API Number: Kenai Alaska, 99611-1949 50-133-20529-00-00 7. Pr Designation (Lease Number): 8. Well Name and Number` t • 1O F~ ~A - 028083 Kenai Belu a Unit 33-6x 9. Field/Pool(s): Kenai Gas Field /Beluga & Tyonek Pools 11. Present Well Condition Summary: Total Depth measured 8,405' feet Plugs (measured) NA feet true vertical 7,844' feet Junk (measured) NA feet Effective Depth measured $,$24' feet Packer (measured) NA feet true vertical 7,7g3' feet (true vertical) NA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 118' 20" 139' 139' 3,060 psi 1,500 psi Surface 1,491' 13-3/8" 1,512' 1,512' 3,450 psi 1,950 psi Intermediate 5,731' 9-5/8" 5,752' 5,246' 6,870 psi 4,750 psi Production 8,341' 3-1 /2" 8,362' 7,801' 10,160 psi t X10 530 psi Liner ~ '~~j~~~' Perforation depth: Measured depth: 6,119' - 8,20T V~~J~ ~ q Z~1Q 1 True Vertical depth: 5,591' - 7,647 ,. . ©~t ~ "~~ Cens. ~' k a Alas TVD Excape 3-1 /2" L-80 8,362' ~tr~~ 7,800' Tubing (size, grade, MD &TVD): Capillary String 3/8" 2205 Stainless Steel 6,119' MD 5,591' ~/D SSSV: NA NA MD NA TVD Packers and SSSV (type, MD &TVD): Packers: NA NA MD NA TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): The 3/8' capillary string was adusted up-hole and reset at 6,119' MD. Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,337 20 1 175 Subsequent to operation: 0 1,950 - 1 218 13. Attachments: 1 . Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations X 1 Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature ~ ~ Phone (907) 283-1371 Date June 15, 2010 V rr' ey Form 10-404 Revised 7/2009 RBDI~,S JUN ~ ! ~~~ Submit Original Only '` Marathon Dperations Summary Report by Job ,,,~~, ~~~ ~ Well Name: KENAI BELUGA UNIT 33-6X Re art Date: 5/272010 Job Cate o R&M MAINTENANCE 24 Hr Summary Disconnect wellhouse power, pull wellhouse, rig up BJ Chemical DynaCoil unit to pull capstring, pull capstring, hole in capstring across from perforations in top module. Rig down for evening Ops Trouble Start Timz End Timz Dur hrs 0 s Code Activi Code Status Code Comment 07:30 08:30 1.00 SAFETY MTG AF Sign in to office pad, receive work permit, travel to 41-7 pad, hold PJSM - topics discussed -slips, trips, falls, active gas production pad, red lights for fire, blue lights for gas emission, siren for audible, muster area, secondary muster, emergency numbers, emergency vehicle, fire extinguishers, eye wash, buddy rule, three second rule, focus and buying into the safety culture. 08:30 11:30 3.OD WAITON EQIP AF Order out crane to pull wellhouse, remove electrical connection to wellhouse, drain gas pressure /soap from cap string 11:30 12:DD 0.50 SAFETY MTG AF PJSM -topics discussed -slips, trips, falls, active gas production pad, red lights for fre, blue lights for gas emission, siren for audible, muster area, secondary muster, emergency numbers, emergency vehicle, fre extinguishers, eye wash, buddy rule, three second rule, focus and buying into the safety culture. 12:00 13:00 1.00 INSTAL SEOP AF Pull wellhouse. Discovered open ended 318 "hose blowing gas. Shut down tD verify that gas was air and not methane. Resume job and pulled wellhouse. 13:00 14:30 1.50 RURD COIL AF Rig up CTU. Set spool onto truck. Split injector, install 318" cap string, set injector head onto well, put tension on cap string, release slips and packoff, set odometer to 7796' (previous set depth), prepare to pull capstring out of well 14:30 18:00 3.5D RUNPUL COIL AF Pull capstring, string moving at 2700# of pull, pull up 300 feet, go back dawn and tag fill at 7994'MD, POOH. When odometer gat to 1671' MD, kinked section came across injector gooseneck. Stopped spooling, cut damaged section out of capillary string, installed connector, removed spooling head, pulled connector onto spool, re-installed spooling head and pulled a second section of cap string out of hole. Larger hole this time. Only approximately 1/4" of circumference not eaten away. Bottome section of cap string in injector. Pulled last 20 feet out of hole with injector. Closed swab valve below chemical injection valve on bottom of cap string. Begin rig down 18:00 18:30 0.50 KURD COIL CS Rig down CTU. Set injector head back onto cradle on truck. 18:30 19:00 0.50 SECURE WELL CS Secure wellhead for evening, turn in work permit and sign out at office pad. Re ort Date: 6132070 Job Cate o R&M MAINTENANCE 24 Hr Summary Previous dynacoil was severed and plugged with sand in sections within perforated interval, This was cutoff and coil was pressure tested and flushed clean, Rig up and run DynaCoil to depth of top perf to avoid severing again, resume pumping soap at 6 gal/day Ops Trouble Start Time End Time Dur hrs 0 s Code Activi Code Status Code Comment 07:30 D8:30 1.00 SAFETY MTG Held Safety Meeting, Completed safe work permit, reviwed JSA, discussed rig up, pressure testing injector head, zero spill policy, wildlife and cell phone use on live pad 08:30 10:30 2.00 RURD COIL Rig up BJ Dyna Coil Unit, Prepare injector head and packoft, Pressure test to 3000psi, change out bottom of cap string (centralizer removed) Fluid Control Valve Set Pressure is 3000psi Max Tool OD is 0.750in 10:30 12:30 2.00 RUNPUL COIL Run in hole with 318 inch cap string, set at depth of 6119ft (depthometer believed 20 ft off so indicator at 6099ft), Set Slips in 11001b's of tension (deviated well, not actual string weight) 12:30 14:30 2.00 RURD COIL Rig Down Coil Unit, 416ft of excess coil was left on the spool next to wellhead, Begin pumping soap at a rate of 6 gal/day www.peloton.com Report Printed: 6115,'2010 API #: 50-133-20529-00-00 Prop. Des: A - 028083 KB Elevation: 82' (21' AGL) Latitude: 12/13/2003 1 /2/2004 TOC (est.) - ???' Excape Svstem Details 'BHP monitoring line volume tank located from 6,055' - 6,093' Excape Svstem Details 20 Conventional modules Module 1 - no flapper valve - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 20 - 6,138' Module 19 - 6,215' Module 18 - 6,298' Module 17 - 6,463' Module 16 - 6,562' Module 15 - 6,700' Module 14 - 6,743' Module 13 - 6,800' Module 12 - 6,879' Module 11 - 7,103' Module 11 - 7,103' Module 10 - 7,141' Module 9 - 7,188 Module 8 - 7,259 Module 7 - 7,320 Module 6 - 7,398' Module 5 - 7,524' Module 4 - 7,812' Module 3 - 7,986' Module 2 - 8,121 Module 1 - NA Ta fill 7,994' w/ Dynacoil (5/27/2010) 7,876' w/ Dynacoil (3/2/2010) " 7,915' wl Dynacoil (5112/2009) KBU 33-6x Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. ~•' ~+T sP >> ± .. ,~ ~q <3 r, .~ ~'', ~ ~) ~ .. y ,. + r TD PBTD 8,405' MD 8,324' MD 7,840' TVD 7,763' TVD M IIARATNON Drive Pipe 20" K-55 133 ppf PE Top Bottom MD 0' 139' TVD 0' 139' Surface Casing 13-318" K-55 68 ppf BTC Top Bottom MD 0' 1,512' TVD 0' 1,512' Cmt wl 320 sks Intermediate Casing 9-518" L-80 47 ppf BTC Top Bottom MD 0' 5,752' TVD 0' 5,246' Cmt w/705 sks Class G Production Tubing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 8,362' TVD 0' 7,800' Cmt w/ 1,150 sks of class G cmt Capillary String (Org. Install 07103/08) 3/8" 2205 Stainless Steel Top Bottom MD 0' 6,119' ND 0' 5,591' i Excape modules placed :u control line fires top 9 modules contol line fires middle modules control line fires bottom modules ~ramic flapper valves below each u1e20 - 6,119'-6,129' ule 19 - 6,196'-6,206' ule 18 - 6,279'- 6,289' ule 17 - 6,444'- 6,454' ule 16 - 6,543'- 6,553' ule 15 - 6,681'- 6,691' ule 14 - 6,724'- 6,734' ule 13 - 6,781'- 6,791' ule 12 - 6,858'- 6,868' ule 11 - 7,084'- 7,094' ule 10 - 7,122'-7,132' ule 9 - 7,169'-7,179' ule 8 - 7,240'- 7,250' ule 7 - 7,301'- 7,311' ule 6 - 7,379'- 7,389' ule 5 - 7,505'- 7,515' ule 4 - 7,791'- 7,801' ule 3 - 7,967'- 7,977' ule 2 - 8,102'- 8,112' ule 1 - 8,197'-8,207' Well Name & Number: Kenai Beluga Unit 33-6x Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 6,119' - 8,207' Perf (TVD): 5,591' - 7,647' Angle @ KOP & Depth: 1.3° / 100 ft @ 1,500' Angle @ Perfs: 8° -~ 5.5° Date Completed: 1/9/2004 Ground Level: (AMSL) RKB: 21' (AGL) Revised by: Kevin Skiba Revision Date: 6/15/2010 • IVlarathvn lMARAiHON Alaska Production LLC Mar~[hon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 RECEIVED March 9, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 MAR I 1 2010 SON&Ga~tCroo~.G°f1 Reference: 10-404 Report of Sundry Well Operations ~12 ~ ~~ Field: Kenai Gas Field o~,V~' Well: Kenai Beluga Unit 33-6x ,~~ _ Dear Mr. Aubert: Attached for your records is the10-404 Report of Sundry Well Operations for KBU 33-6x well. This report covers the work performed to raise the 3/8" capillary string up-hole 109'. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~~ .,~/!i7/~.v Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALAS AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~~~I~~~ED MAR ~ 1 2U1Q 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ tring Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ Ad'ustment 2. Operator Marathon Alaska Production LLC 4. Well Class Before Work: Permit to Drill Number: Name: Development ~ Exploratory^ 203-183 3. Address: PO Box 1949 Stratigraphic ^ Service ^ .API Number: Kenai Alaska, 99611-1949 50-133-20529-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ~ A - 028083 `Kenai Belu a Unit 33-6x 9. Field/Pool(s): ~ Kenai Gas Field /Beluga & Tyonek Pools 11. Present Well Condition Summary: Total Depth measured 8,405' feet Plugs (measured) NA feet true vertical 7,844' feet Junk (measured) NA feet Effective Depth measured 8,324' feet Packer (measured) Nq feet true vertical 7,763' feet (true vertical) NA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 118' 20" 139' 139' 3,060 psi 1,500 psi Surface 1,491' 13-3/8" 1,512' 1,512' 3,450 psi 1,950 psi Intermediate 5,731' 9-5/8" 5,752' 5,246' 6,870 psi 4,750 psi Production 8,341' 3-1/2" 8,362' 7,801' 10,160 psi 10,530 psi Liner Perforation depth: Measured depth: 6,119' - 8,207' True Vertical depth: 5,591' - 7,647' Excape 3-1/2" L-80 8,362' MD 7,800' TvD Tubing (size, grade, MD &TVD): Capillary String 3/8" 2205 Stainless Steel 7,796' MD 7,238' TVD SSSV: NA NA MD NA TVD Packers and SSSV (type, MD &TVD): Packers: NA NA MD NA T~/D 11. Stimulation or cement squeeze summary: Intervals treated (measured): The 3/8' capillary string was adusted up-hole 109' and Treatment descriptions including volumes used and final pressure reset at 7,796' MD. : 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,265 71 1 265 Subsequent to operation: 0 1,665 - 1 151 13. Attachments: '~ Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development 0 Service ^ Daily Report of Well Operations X .Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba - Title Regulatory Compliance Technician Signature _ ~ ~ Phone (907) 283-1371 Date March 9, 2010 ~ ntsDMS MAR 12 2010 ~~rn--, Form 10-404 Revised 7/2009 Submit Original Only IVlera'dtat ations Summary Report by Job ,~~ ®Q;~ryN e j Name: KENAI BELUGA UNIT 33-6 Otr/0tr, Block, Sec, Town, Range Field Name License No. State/Province Country Sec.6, T4N, R11W, S.M. KENAI ALASKA USA Daily Operations Report Date: 2126/2010 Job Cate o R&M MAINTENANCE 24 Hr Summary Pull capstring, prep well to run PLT Ops Trouble Start Time.. End Time Dur (hrs} Ops Cade Activity Cade Status Code Comment 15:00 16:30 1.50 RURD -- COIL AF - _ -- Move BJ DynaCoil unit from KBU 14-6Y to KBU 33-6X. Lay down containment, spot unit. Move manlift and light plant. Prepare DynaCoil to be pulled from well. Rig up CTU, spool and run excess coil onto spool. Release packoff and prepare to pull capillary string from well. 16:30 18:00 1.50 RUNPUL COIL AF Pull DynaCoil set at 7905' MD out of well. No sticking issues. 18:00 18:45 0.75 RURD COIL AF Rig down coil unit, remove packoff, set injector head back into cradle, secure Hite cap onto flange. 18:45 19:00 0.25 SECURE WELL AF Secure wellhead for evening, turn in work permit. Prepare to run PLT tomorrow Report Date: 2/2712010 Job Cate o R&M MAINTENANCE 24 Hr Summary Run production log passes from Module 5 up, shut well in and make shut in passes at one hour, two hour, four hour and eight hours. i Ops Trouble ', Start Time '. End Time Dur (hrs) '~ _ _ Ops Code j Activity Code Status Code Comment _ 07:30 08:30 1.00 SAFETY MTG AF Arrive location, obtain work permit and hold PJSM -review JSA's, assign jobs, slips, trips, falls, overhead loads, changing weather, ice under snow, pressure testing packoff, environmental issues with soap and methanol, emergency numbers, emergency vehicles, muster area, red lights for fire, blue lights for gas emission, sirens for audible, buddy rule, three second rule. This job will be a long one, so everyone needs to maintain their focus and rotate in and out of the sleeper if needed. 08:30 09:30 1.00 RURD ELEC AF Rig up wireline truck, crane truck and lubricator. Stab lubricator and BOP onto wellhead and pressure test to 1500# -test successful. 09:30 11:00 1.50 RUNPUL ELEC AF Run gauge ring 2.25" OD with 1.6" swage. Sat down in Module #5 flapper area at 7536' MD. Worked area, couldn't get through, run correlation, POOH 11:00 11:30 0.50 TEST WLHD AF Change out gauge ring to PLT. Pressure test QC sub to 1500# -test successful 11:30 00:00 12.50 RUNPUL ELEC AF Perform station measurement at surface - 286# and 62 deg F Perform station measurement above perforation at 5975' MD - 558 # and 111 deg. F. Perform 60 fpm, 90 fpm and 120 fpm up and down passes from top of perforations to 7500 ft. MD. Well shut in at 14:20 hours. Log shut in passes at 15:20, 16:20, 18:20 and 22:20 hours. POOH At surface at 11:35 pm. 00:00 00:30 0.50 RURD ELEC AF Rig down wireline truck, lubricator and crane truck. Break lubricator at OC and install Hite cap. Pressure test cap, shut in upper and lower master, swab valve and wing valve. 00:30 00:45 0.25 SECURE WELL AF Check valve positions to verify closure. Secure location for weekend. Turn off light plant, turn in work permit.. Report Date: 3I2I2010 Job Cate o R&M MAINTENANC E _ 24 Hr Summa ry Well shut i n over the weekend. Run PT survey to determine fluid level. -- Ops Trouble ~, Start Time End Time Dur (hrs) Ops Code Activity Cade ! Status Code Comment ~' 09:00 10:00 1.00 SAFETY MTG AF Arrive location- received work permit, hold PJSM -topics discussed - Reviewed JSA's, assigned tasks, slips, trips, falls, overhead loads, pinch points, working with high pressure. Start the job by assessing work site for icy conditions, spreading sand out over work area to minimize icy slips. Emergency phone numbers, muster areas, wind directions, red lights for fire, blue lights for gas emission, sirens for audible. Emergency vehicle. Use the buddy rule, three second rule. Focus on the job. 10:00 10:45 0.75 RURD ELEC AF Rig up wireline unit, crane truck and BOP /lubricator. Pressure test lubricator to 1500# -test successful. 10:45 15:30 4.75 RUNPUL ELEC AF Run pressure temperature survey. Surface wellhead pressure 1180# on gauge and 1168 on wireline sensor. Fluid level at 7310' MD. Tool set down at bottom of Module #5 around flapper area. Depth was 7536' MD. Made 5 minute stationary measurement there and back at surface. 15:30 16:00 0.50 RURD ELEC AF Rig down wireline unit, BOP and lubricator, crane truck. www.peloton.com Page 1/2 Report Printed: 3/8/2010 INar~'dtpn ations Summary Report by Jo~ ,I~~TMOM ®pj~ny Name: KENAI BELUGA UNIT 33-6 Casing Flange Elevation (ft) Ground Elevation (ft) KB-Casing Flange Distance (ft) KB-Ground Distance (ft) Spud Date Rig Release Date Start Time End Time - -, -- Dur (hrs) Ops Code: ' Activit Code v 1 Qps Status _ Trouble Code __-- _ - -- -- Comment 16:00 16:15 0.25 SECURE _. WELL _ ____ AF __. Secure wellhead for evening, turn in work permit, leave location. Daily Operations Report Date: 313/2010 Job Cate o R&M MAINTENANCE ___ 24 Hr Summary MIRU BJ Dynacoil. Re-run capstring and tag @ 7,876' MD RKB, work string, and fell to 7,959'. Pull up and set capstring @ 7,796' (Module 4). Set foamer @ 4.5 gal/day. RD BJ. Re-install wellhouse. Start Time End Time ' Dur{hrs) Ops Code Activity Code Ops Status Trouble Code . I , Comment 07:00 08:30 1.50 SAFETY MTG AF Attended monthly KGF safety meeting. 08:30 09:15 0.75 SAFETY MTG AF Held PJSM w/ BJ Dynacoil and operator. Discussed slippery conditions, working with chemicals, and fall protection. Obtained safe work permit. 09:15 10:45 1.50 RURD COIL AF RU Dynacoil unit and equipment. Bench test packoff, OK. Set FCV @ 3500psi. Pull test BHA to 600#, good test. Land injector on wellhead. 10:45 11:00 0.25 TEST BOPE AF PT packoff to 2000psi, good test. 11:00 14:30 3.50 RUNPUL COIL AF RIH w/ 3/8" capillary string w/ FCV, and sinker bar w/ 2.25" OD centralizer fins. Tag @ 7876' MD RKB and work tool. Fell through to 7959'. PUH to 7796' (Module 4) and set cap string. 14:30 15:30 1.00 RURD COIL AF RD Dynacoil unit and equipment. Unload spool and set foamer @ 4.5 gal/day. Turn in safe work permit, sign out, and leave location. 15:30 16:00 0.50 SAFETY MTG AF Held PJSM w/ Pollard and operator to re-install wellhouses. Discussed crane operations, muster areas, and slippery conditions. Obtained safe work permit. 16:00 17:30 1.50 RURD EQIP AF Install wellhouses on KBU 14-6Y and KBU 33-6X. Sign out, turn in work permit, and leave location. I www.peloton.com Page 2/2 Report Printed: 3/8/2010 • 50-133-20529-00-00 s: A - 028083 ~tion: 82' (21' AGL) KBU 33-6x Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11 W, S.M. 12/13/2003 1 /2/2004 Excaoe Svstem Details -BHP monitoring line volume tank located from 6,055' - 6,093' Excaoe Svstem Details 20 Conventional modules Module 1 - no flapper valve - Ceramic flapper valves below each module as follows: Flaoaers MD IRKeI: Module 20 - 6,138' Module 19 - 6,215' Module 18 - 6,298' Module 17 - 6,463' Module 16 - 6,562' Module 15 - 6,700' Module 14 - 6,743' Module 13 - 6,800' Module 12 - 6,879' Module 11 - 7,103' Module 11 - 7,103' Module 10 - 7,141' Module 9 - 7,188 Module 8 - 7,259 Module 7 - 7,320 Module 6 - 7,398' Module 5 - 7,524' Module 4 - 7,812' Module 3 - 7,986' Module 2 - 8,121 Module 1 - NA Ta fill - 7,876' w/ Dynacoil (3/2/2010) - 7,915' w/ Dynacoil (5/1 212 0 0 9) L~ M Mruu-n~oM Drive Pioe 20" K-55 133 ppf PE Top Bottom M D 0' 139' ND 0' 139' surface Casing 13-318" K-55 68 ppf BTC Top Bottom MD 0' 1,512' ND 0' 1,512' Cmt w/ 320 sks termediate Casing 9-518" L-BO 47 ppf BTC Top Bottom MD 0' 5,752' ND o' s,zae' Cmt w/705 sks Class G ~oduction Tubing t-1/2" L-80 9.3 ppf Mod EUE Top Bottom Srd MD 0' 8,362' ND 0' 7,800' Cmt wl 1,150 sks of class G cmt Caoillarv Strinn (Installed 07103108) 318" 2205 Stainless Steel Top Bottom MD 0' 7,796' ND 0' 7,238' Beluga / Tvonek Excaae Details - 20 Excape modules placed - Red control line fires top 9 modules - contol line fires middle 8 modules -Green control line fires bottom 3 modules - Ceramic flapper valves below each module Perfs MD (RKBI: Module 20 - 6,119'-6,129' Module 19 - 6,196'-6,206' Module 18 - 6,279'- 6,289' Module 17 - 6,444'- 6,454' Module 16 - 6,543'- 6,553' Module 15 - 6,681'- 6,691' Module 14 - 6,724'- 6,734' Module 13 - 6,781'- 6,791' Module 12 - 6,858'- 6,868' Module 11 - 7,084'- 7,094' Module 10 - 7,122'-7,132' Module 9 - 7,169'-7,179' Module 8 - 7,240'- 7,250' Module 7 - 7,301'- 7,311' Module 6 - 7,379'- 7,389' Module 5 - 7,505'- 7,515' Module 4 - 7,791'- 7,801' Module 3 - 7,967'- 7,977' Module 2 - 8,102'- 8,112' Module 1 - 8,197'- 8,207' Well Name & Number: Kenai Beluga Unit 33-6x Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 6,119' - 8,207' Perf (TVD): 5,591' - 7,647' Angle @ KOP & Depth: 1.3° / 100 ft @ 1,500' Angle @ Perfs: 8° --~ 5.5° Date Completed: 1/9/2004 Ground Level: (AMSL) RKB: 21' (AGL) Revised by: Craig Rang Revision Date: 3/9/2010 TD PBTD 8,405' MD 8,324' MD 7,840' TVD 7,763' TVD • IU'larathon ,~A~ Alaska Production LLC ~ October 14, 2009 NI'~rathon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~ Y ~D QGT 1 +~ ZOQ~ Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations ~18sk~ Oil ~ Gas Cons. Gorr~mi~~i-~:; Anchorape ~3~' ~~ o~ Field: Kenai Gas Field Well: Kenai Beluga Unit 33-6x . ~~~~ _~r, < Dear Mr. Aubert: Attached for your records is the10-404 Report of Sundry Well Operations for KBU 33-6x well. The AOGCC provided approval for the addition of 91' of perforations under Sundry # 308-353. Marathon no longer intends to perform this activity and is closing out this sundry as a Non-Work activity.'~Other wells in this program experienced reduced production when perforated, which was caused by additional water infiltrating the wellbore. This decision is intended to minimize the risk of lo~ing crucial production while entering the high demand season. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~ _~/UU''t~' ~ Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMM~ON ~~~EIO/E~ ~C~ ~. ~ ~lzO°4 REPORT OF SUNDRY WELL OPERATIONS ~~~~~~ ~~~ ~~;a~ ~;ans. Commission An~l~nr~na 1. Operations Abandon Repair Well Plug PerForations Stimulate Other ~ Non-Work of Performed: Alter Casing ~ Pull Tubin~ Perforate New Pool ~ Waiver^ Time Extension ^ pert additions Change Approved Program ~ Operat. Shutdowr0 PerForate ~ Re-enter Suspended Well ~ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^~ Exploratory~ 203-183 3. Address: PO Box 1949 StraYigraphic ^ Service Q 6. API Number: Kenai Alaska, 99611-1949 50-133-20529-00-00 7. KB Elevation (ft): ~ 9. Well ame and Number: ~ 82' (21' AGL) Kenai Belu a Unit 33-6x 8. Properry Designation: ~ 0. Field/Pool(s): A-028083 Kenai Gas Field / Beluga 8~ Tyonek Pools 11. Present Well Condition Summary: ~ Total Depth measured $,405' feet Plugs (measured) N/A true vertical 7~g44' feet Junk (measured) N/A Effective Depth measured $,324' feet true vertical 7,763' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 118' 20" 139' 139' 3,060 psi 1,500 psi Surface 1,491' 13-3/8" 1,512' 1,512' 3,450 psi 1,950 psi Intermediate 5,731' 9-5/8" 5,752' S,246' 6,870 psi 4,750 psi Production 8,341' 3-1/Z" 8,362' 7,801' 10,160 psi 10,530 psi Liner Perforation depth: Measured depth: 6,119' - 8,207' True Vertical depth: 5,591' - 7,647' Excape Tubing 3-1/2" L-80 8,362' Tubing: (size, grade, and MD) Capillary String 3/8" 2205 Stainless Steel 7,920' Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): The approved pertoration additions were not added because of the additional water infiltration issues experience with some of the other Treatment descriptions including volumes used and final pressure: wells, in this program, after they were perforated. 13. Representative DailyAverage Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments: . Well Class afterwork: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service ~ Daily Report of Well Operations . Well Status after work: il ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-353 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba ~ Title Regulatory Compliance Technician ~ Signature ,~~ t Phone (907) 283-1371 Date October 14, 2008 _ ~ ~s ~~~ ~ ~r~-z Form 10-404 Revised 04/2006 ~ Submit Original Only . . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 24, 2008 7:29 AM To: 'Skiba, Kevin J.' Subject: RE: KBU 33-6X (203-183) Thanks Kevin. Just following up with what was authorized by the sundry. Best wishes for the holidays. Tom Maunder, PE AOGCC From: Skiba, Kevin 7. [mailto:kskiba@marathonoil.com] Sent: Wednesday, December 24, 2008 7:24 AM To; Maunder, Thomas E (DOA) Subject: RE: KBU 33-6X (203-183) Tom, We decided to postpone adding these perforations until warming weather. Two of the other wells that were in the perforating program produced water when perforated. We did not want to risk loosing any more production during this season of high demand. We decided to reinstall the capillary string until we're ready to proceed. I apologize for not making mention of postponing the perforating, Kevin Skiba Engineering Technician Marathon Oil Company Office (907) 283-1371 Cell (907} 394-1332 Fax (907) 283-1350 ~4~ ~r e L~el~}~ [~f t~~~~ K C~' t._ Bf .S p, From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 23, 2008 4:02 PM To: Skiba, Kevin J. Subject: KBU 33-6X (203-183) Kevin, I am looking at the 404 submitted for the recent work shortening the capillary string. I note that the string was pulled from the well 10!29/08 and was re-run 11!17/08. A sundry (308-353) was issued on November 3 to add perforations to the well. Removing the capillary string was necessary to add the perfs. Were new perforations added to the well? is so, those operations should also be reported. Thanks in advance. Tom Maunder, PE AOGCC 12/24/2008 M Marathon MARATHON Oil Company November 25, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Beluga Unit 33-6x Dear Mr. Maunder: Marathon Oii Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~,~:., ,~ ~~~ Attached for your records is the10-404 Report of Sundry Well Operations for KBU 33-6x well. This report covers the work performed to raise the capillary string up-hole 30'. The new setting depth is 7,920' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, r ~~ ~Q~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS v y~rV~ • STATE OF ALASKA m~1~ ~/v ALASKA OIL AND GAS CONSERVATION COMMON ~ REPORT OF SUNDRY WELL OPERATIONS ~~a~~ab /0?-80~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Raised - Performed: Alter Casing [] Pull Tubin~ Perforate New Pool ^ Waiver^ Time Extension ^ Capillary String Change Approved Program ^ Operat. Shutdowr^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company Na e 4. Well Class Before Work: 5. Permit to Drill Number: m : Development Q, Exploratory^ 203-183 - 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20529-00-00 7. KB Elevation (ft): 9. Well Name and Number: 82' (21' AGL) ~ Kenai Belu a Unit 33-6x- 8. Property Designation: 10. Field/Pool(s): A-028083 - Kenai Gas Field /Beluga & Tyonek Pools 11. Present Well Condition Summary: Total Depth measured 8,405' , feet Plugs (measured) N/A true vertical 7,844'- feet Junk (measured) N/A Effective Depth measured $,324' - feet _ true vertical 7,763' ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 118' 20" 139' 139' 3,060 psi 1,500 psi Surface 1,491' 13-3/8" 1,512' 1,512' 3,450 psi 1,950 psi Intermediate 5,731' 9-5/8" 5,752' 5,246' 6,870 psi 4,750 psi Production 8,341' 3-1/2" 8,362' 7,801' 10,160 psi 10,530 psi Liner Perforation depth: Measured depth: 6,119' - 8,207' True Vertical depth: 5,591' - 7,647' Excape Tubing 3-1/2" L-80 8,362' Tubing: (size, grade, and MD) Capillary String 3/8" 2205 Stainless Steel 7,920' Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Raised capillary string up-hole 30' to 7,920'. Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,380 110 1 431 Subsequent to operation: 0 1,955 - 1 350 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas^- WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 2 ~~~- J Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature ~ Phone (907) 283-1371 Date November 25, 2008 Form 10-404 Revised 04/2006 ~ _~ ~ ~ ~ .F s ~~~~ ;~~~~\~ Submit Original Only ~~~ ~ J~ • 50-133-20529-00-00 s: A - 028083 Rion: 82' (21' AGL) 12/13/2003 1 /2/2004 KBU 33-6x Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. ~- '_ - - ~+ 1~: Excape Svstem Details - BHP monitoring line volume tank located from 6,055' - 6,093' Capillary String 318" 2205 Stainless Steel Top Bottom MD 0' 7,920' TVD 0' 7,361' BHP monitoring line volume tank located from 6,055' - 6,093' Ceramic flapper valves below each module as follows: Module 20 - 6,147.5' Module 19 - 6,223.8' Module 18 - 6,306.4' Module 17 - 6,470.9' Module 16 - 6,572.5' Module 15 - 6,709.5' Module 14 - 6,752.4' Module 13 - 6,809.3' Module 12 - 6,887.5' Module 11 - 7,110.3' Module 11 - 7,110.3' Module 10 - 7,149.3' Module 9 - 7,196.1' Module 8 - 7,266.3' Module 7 - 7,327.5' Module 6 - 7,407.7' Module 5 - 7,532.4' Module 4 - 7,822.2' Module 3 - 7,995.5' Module 2 - 8,131.5' Module 1 - NA Y; t' 1% t til.' Y" r +. :~' S.' 1+ .. r; 1~ • M MQ~2ATHON J'I Drive Pipe J 20" K-55 133 ppf PE Top Bottom M D 0' 139' TVD 0' 139' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,512' TVD 0' 1,512' Cmt w/ 320 sks Intermediate Casin g 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 5,752' TVD 0' 5,246' Cmt w/ 705 sks Class G Production Tubing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 8,362' TVD 0' 7,800' Cmt wl 1,150 sks of class G cmt Red control line fires top 9 modules contol line fires middle 8 modules Gree-, control line fires bottom 3 modules Ceramic flapper valves below each module TD PBTD 8,405' MD 8,324' MD 7,840' TVD 7,763' TVD Module 20 - 6,119'-6,129' Module 19 - 6,196'-6,206' Module 18 - 6,279'- 6,289' Module 17 - 6,444'- 6,454' Module 16 - 6,543'- 6,553' Module 15 - 6,681'- 6,691' Module 14 - 6,724'- 6,734' Module 13 - 6,781'- 6,791' Module 12 - 6,858'- 6,868' Module 11 - 7,084'- 7,094' Module 10 - 7,122'- 7,132' Module 9 - 7,169'- 7,179' Module 8 - 7,240'- 7,250' Module 7 - 7,301'- 7,311' Module 6 - 7,379'- 7,389' Module 5 - 7,505'- 7,515' Module 4 - 7,791'- 7,801' Module 3 - 7,967'- 7,977' Module 2 - 8,102'- 8,112' Module 1 - 8,197'- 8,207' Well Name & Number: Kenai Beluga Unit 33-6x Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): (TVD): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 1/9/2004 Completion Fluid: 6% KCL Revised by: Mickey Mullin Last Revison Date: 11/17/2008 ~k~ ~~ ,. "ter ~/ r~ ~„~ ~ E--` ~ ,.T ,~, ~~ ~~ ~ ~ ~ S ~ ~ ~ ~ ~ ~ tt ~ ~ ~~1 '~~ ~'sA~ 11 ~' ~=~ --~ ~ ~ ~-~ ~ R~~ i SARAH PALIN G -__,~ ~~~ OVERNOR CQ~S"~i R~~-~O OM~*. I~ 333 W. 7th AVENUE, SUITE 100 1•~1~11-7~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Kevin Skiba FAx (907) z7s-7x42 Engineering Technician Marathon Oil Company t , ~ ~~ ~~~ ~~$~ ~ ~~ ~~ ;_ PO Box 1949 Kenai AK 99611-1949 I (~ 3 ~d.3 ~ ` o Re: Kenai Gas Field, Upper Tyonek/Beluga Gas Pool, KBU 33-6x Sundry Number: 308-353 Dear Mr. Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please none the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~,,~ Chair DATED this -day of October, 2008 Encl. M Marathon MARATHON Oil Company September 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Application of Sundry Approvals Field: Kenai Gas Field Well: Kenai Beluga Unit 33-6x Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Attached for your records is the10-403 Application of Sundry Approvals for KBU 33-6x well. Marathon proposes to enhance gas production by adding 91' of perforations to the Beluga formation. The proposed perforations will be placed across 5 intervals: MD TVD ft 5,870'-5,890' 5,356'-5,375' 20' 5,934'-5,951' 5,416'-5,432' 17' 6,828'-6,844' 6,280'-6,295' 16' 6,887'-6,900' 6,338'-6,351' 13' 7,320'-7,345' 6,766'-6,791' 25' Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, • ~/ Kevin J. Skiba Engineering Technician Enclosures: 10-403 Application of Sundry Approvals Well Schematic Perforation Procedure cc: Houston Well File Kenai Well File KJS MDD d' " ~/~~D ~ STATE OF ALASKA I~/ ALA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon^ Suspend ^ Operational shutdown^ Perforate ~ ~ Waiver^ ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon OII Con1 an p y 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 203-183 3. Address: p0 BOx 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20529-00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: S ^ ~ Kenai Beluga Unit 33-6x - pacing Exception Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A 028083 82' (21' AGL) Kenai Gas Field /Beluga & Tyonek Pools 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,405' - 7,844' - 8,324'- 7,763' - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 118' 20" 139' 139' 3,060 psi 1,500 psi Surface 1,491' 13-3/8" 1,512' 1,512' 3,450 psi 1,950 psi Intermediate 5,731' 9-5/8" 5,752' 5,246' 6,870 psi 4,750 psi Production 8,341' 3-1 /2" 8,362' 7,801' 10,160 psi 10,530 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,119'-8,207' 5,591'-7,647' Excape Tubing 3-1 /2" L-80 8,362' Capillary Tubing 3/8" 2205 Stainless Steel 7,950' Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ^ Exploratory ^ Development ^~ - Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 20, 2008 Oil ^ Gas ^~ - Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature _ ~ Phone (g07) 283-1371 Date September 30, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~~ 353 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~ APPROVED BY I A roved b : • e ~ COMMISSIONER THE COMMISSION Date: ` pp y i~~8 .~~``~ M~ Other Form 10-403 Revised 06/2006^ ~ ~ ^ ~ ~~ H ~ , ~~. ~~~ ~ ~ ~oo~ Submit in Duplicate M MARATHON • • September 17, 2008 Marathon Oil Corporation Field: Kenai Beluga Unit Pad: 41-7 WBS: Not requested yet KBU 33-6X Well Status: 3.256 MMcf/d @ 455 psi (SCADA 9-18-08) and 80 bwpd (TOW 9-15-08). Objective: Perforate five Beluga sands. Depths and surface pressure to fire guns: 5870' - 5890' (20' net, 20' single run) - 630 psi 5934' - 5951' (17' net, 10' & 6' tandem single run) - 640 psi 6828' - 6844' (16' net, 10 & 6' tandem single run) - 1000 psi 6887' - 6900' (13' net, 14' single run) -1470 psi 7320' - 7345' (25' net, 10' & 14' tandem single run) - 770 psi Guns to be used: 2-3/8" RTG (Retrievable Tubing Gun) guns loaded 4 SPF 60 degree-phased with TAG-2375-402NTX charges and PX-1 firing head. API target performance: 0.27" entrance hole and 19.21" penetration. Max gun swell in air: 2.575" OD. Procedure• Note: this operation will take several days, and the start date is dependent on Dyna-Coil's arrival in Alaska. Spool Length String Estimated Maximum When Fluid Perf Well Pulled Depth Level Depth KBU 33-6X Unknown 7950' 7850' 8207' 1. Remove capillary string (3/8" 2205 0.049" WT) a) Remove well house. b) Have on site: Sundry. Safe Work Permit. JSA. c) Remove tagout straps and signs; disconnect spool tubing. d) MIRU BJ Dyna-Coil unit and spool (P/U Dyna-Coil injector with crane). e) Release Rattiguns. Pull tubing. Save coil for rerunning in the well after perfs. f) RDMO. Cleanup site. Sign-out. Do not replace well house. • • 2. a) MI diesel man-lift. b) MIRU Expro E-line service with full lubricator, pump-in sub, flow tubes, and pressure control equipment. c) Hold PJSM. d) PT lubricator to 2000 psi (MPSP+) with KCL H2O or methanol, weather dependent. e) RIH with 2.75" GR to minimum depth needed for CCL correlation. POOH GR. 3. a) RIH w/ 25' of guns (type shown above, 14' & 10' tandem guns). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain 770 psi WHP (underbalanced at 40% DD). d) Pull up into position and shoot 7320' - 7345' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. e) LD spent perf gun. NOTE: we will shoot as many sections as we can per day. When we need to rig down for the day, we will lay down the injector and flow test overnight. When starting the next day, follow the RU procedure. 4. a) b) RIH w/ 13' of guns (type shown above, 14' gun). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain 1470 psi WHP (underbalanced at 40% DD). d) Pull up into position and shoot 6887' - 6900' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. e) LD spent perf gun. 5. a) RU Expro. b) RIH w/ 16' of guns (type shown above, 10' & 6' tandem guns, single run). c) Correlate Expro CBL/GR/CCL log depth to open-hole logs. d) SI well long enough to obtain 1000 psi WHP (underbalanced at 40% DD). e) Pull up into position and shoot 6828' - 6844' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. f) LD spent perf gun. 6. a) RU Expro. b) RIH w/ 17' of guns (type shown above, 10' & 6' tandem guns, single run). c) Correlate Expro CBL/GR/CCL log depth to open-hole logs. d) SI well long enough to obtain 640 psi WHP (underbalanced at 40% DD). e) Pull up into position and shoot 5934' - 5951' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. f) LD spent perf gun. KBU 33-6x Add perfs - MDD 9/30/2008 10:15:30 AM s 7. a) RU Expro b) RIH w/ 20' of guns (type shown above, 20' guns, single run). c) Correlate Expro CBL/GR/CCL log depth to open-hole logs. d) SI well long enough to obtain 630 psi WHP (underbalanced at 40% DD). e) Pull up into position and shoot 5870' - 5890' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. f) LD spent perf gun and lubricator. g) RD Expro, return well to production, and flow test 8. Produce well to sales. CONTACTS Ken Walsh: 907-283-1311 (w) 907-394-3060 (c) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (c) KGF Operators: 907-283-1305 MD Bottom Perf 7345 6900 6844 5951 5890 TVD Bottom Pef 6791 6351 6295 5432 5375 Formation Pressure' 1490 2853 1885 1195 1180 Jennifer Enos: Clyde Scott 40% dd Formation Pressure 894 1712 1131 717 708 BHT tem p 713-296-3319 (w) 713- 408-3583 (c) 713-296-2336 (w) (WAM calculated) radient) Surface pressure to fire guns 125 76 120 147 119 99 110 63 109 62 *All formation pressures are rough estimates. Be conservative on shooting pressure. KBU 33-6x Add perfs - MDD 9/30/2008 10:15:30 AM • 50-133-20529-00-0 s: A - 028083 ~tion: 82' (21' AGL) 12/13/2003 1 /2/2004 KBU 33-6x Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11 W, S.M. M MARATNOM JII Drive Pipe J 20" K-55 133 ppf PE Top Bottom M D 0' 139' TVD 0' 139' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,512' TVD 0' 1,512' Cmt w/ 320 sks Intermediate Casin g 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 5,752' TVD 0' 5,246' Cmt w/ 705 sks Class G Production Tubing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 8,362' TVD 0' 7,800' Cmt w/ 1,150 sks of class G cmt Excape System Details -BHP monitoring line volume tank located from 6,055' - 6,093' Capillary String 3/8" 2205 Stainless Steel Top Bottom MD 0' 7,950' TVD 0' 7,950' 3HP monitoring line volume tank located from 6,055' - 6,093' ceramic flapper valves below each module as follows: Module 20 - 6,147.5' Module 19 - 6,223.8' Module 18 - 6,306.4' Module 17 - 6,470.9' Module 16 - 6,572.5' Module 15 - 6,709.5' Module 14 - 6,752.4' Module 13 - 6,809.3' Module 12 - 6,887.5' Module 11 - 7,110.3' Module 11 - 7,110.3' Module 10 - 7,149.3' Module 9 - 7,196.1' Module 8 - 7,266.3' Module 7 - 7,327.5' Module 6 - 7,407.7' Module 5 - 7,532.4' Module 4 - 7,822.2' Module 3 - 7,995.5' Module 2 - 8,131.5' Module 1 - NA Red control line fires top 9 modules contol line fires middle 8 modules Greer, control line fires bottom 3 modules Ceramic flapper valves below each module Module 20 - 6,119'-6,129' Module 19 - 6,196'-6,206' Module 18 - 6,279'- 6,289' Module 17 - 6,444'- 6,454' Module 16 - 6,543'- 6,553' Module 15 - 6,681'- 6,691' Module 14 - 6,724'- 6,734' Module 13 - 6,781'- 6,791' Module 12 - 6,858'- 6,868' Module 11 - 7,084'- 7,094' Module 10 - 7,122'- 7,132' Module 9 - 7,169'- 7,179' Module 8 - 7,240'- 7,250' Module 7 - 7,301'- 7,311' Module 6 - 7,379'- 7,389' Module 5 - 7,505'- 7,515' Module 4 - 7,791'- 7,801' Module 3 - 7,967'- 7,977' Module 2 - 8,102'-8,112' Module 1 - 8,197'-8,207' TD PBTD 8,405' MD 8,324' MD 7,840' TVD 7,763' TVD Well Name & Number: Kenai Beluga Unit 33-6x Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): (TVD): Angle/Perfs: Angle ~ KOP and Depth: Dated Completed: 1/9/2004 Completion Fluid: 6% KCL Prepared By: Kevin Skiba Last Revison Date: 9/30/2008 M Marathon MARATHON Oil Company July 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations .: Field: Kenai Gas Field ~'~'~'~~ AUK ~ ~ 208 Well: Kenai Beluga Unit 33-6x Dear Mr. Maunder: Attached for your records is the10-404 Report of Sundry Well Operations for KBU 33-6x well. This report covers the capillary string installation performed under Sundry #308- 220. The capillary string was installed on 7/4/2008 and set at a depth of 7,950' MD. Please contact me at (907} 283-1371 if you have any questions or need additions! information. Sincerely, ~'~., ~ ~ ice.. Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations Well Schematic Operations Summary • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~_a cc: Houston Well File Kenai Well File KJS DMD ~3 ~~~ ~~ ~ ~- -508 r ~'"'~ .~ ~.~„ STATE OF ALASKA AL~i4 OIL AND GAS CONSERVATION COM SION ~ tt,) TL~ ~? REPORT OF SUNDRY WELL OPERATIO~V~ ~~. > ~ ~ 1. Operations Abandon Repair Well Plug-Perforations Stimulate Ot , ~ ~~? Install Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Capillary String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame; Development^ % Exploratory^ 203-183' 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20529-OQ-00 7. KB Elevation (ft): 9. Well Name and Number: 82' 21' AGL ' Kenai Belu a Unit 33-6x+ 8. Property Designation: 10. Field/Pool(s): Fes' A-028083 Kenai Gas Field /Beluga 8~ Tyonek Pools 11. Present Welt Condition Summary: Total Depth measured $405' - feet Plugs (measured) N/A true vertical 7gg4'- feet Junk (measured) N/A Effective Depth measured 8324' - feet true vertical 7763'- feet Casing Length Size MD TVD Burst Collapse Structural Conductor 139' 20" 139' 139' 3,060 1,500 Surface 1,512' 13-3/8" 1,512' 1,512' 3,450 1,950 Intermediate 5,752' 9-5/8" 5,752' 5,246' 6,870 4,750 Production 8,362' 3-1/2" 8,362' 7,801' 10,160 10,530 Liner Perforation depth: Measured depth: 6,119'-8,207' True Vertical depth: 5,591'-7,647' Excape Tubing 3-1/2" L-80 8,362' Tubing: (size, grade, and MD) Capillary String 3/8" 2205 Stainless Steel 7,950' Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,075 85 1 309 Subsequent to operation: 0 2,455 74 1 314 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-220 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician ~~ ~~~~ ~~~~ Signature ~~~.(. ~ ~~, ~Y/vL Phone (907) 283-1371 Date July 30, 2008 Form 10-404 Revised 04/2006 V ~ ,l ? ~'~ ~ ~ ~ ~ 1~f°~.. ~;~J~j ~ ~ 100 Submit Original Only :, ~ L • 203-183 50-133-20529-00-00 s: A - 028083 Rion: 82' (21' AGL) 12/13/2003 1 /2/2004 Excaae Svstem Details - BHP monitoring line volume tank located from 6,055' - 6,093' Caoillarv Strinn 318" 2205 Stainless Steel Top Bottom MD 0' 7,950' TVD 0' 7,950' BHP monitoring line volume tank located from 6,055' - 6,093' Ceramic flapper valves below each module as follows: Moduie 20 - 6,147.5' Module 19 - 6,223.8' Module 18 - 6,306.4' Module 17 - 6,470.9' Module 16 - 6,572.5' Module 15 - 6,709.5' Module 14 - 6,752.4' Module 13 - 6,809.3' Module 12 - 6,887.5' Module 11 - 7,110.3' Module 11 - 7,110.3' Moduie 10 - 7,149.3' Module 9 - 7,196.1' Module 8 - 7,266.3' Module 7 - 7,327.5' Module 6 - 7,407.7' Module 5 - 7,532.4' Module 4 - 7,822.2' Module 3 - 7,995.5' Module 2 - 8,131.5' Module 1 - NA ,? ~,. MARATHON Drive Pioe 20" K-55 133 ppf PE Top Bottom M D 0' 139' TVD 0' 139' Surface Casing 133/8" K-55 68 ppf BTC Top Bottom MD 0' 1,512' TVD 0' 1,512' Cmt w/ 320 sks Intermediate Casin o 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 5,752' TVD 0' 5,246' Cmt w1705 sks Class G Production Tubing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 8,362' TVD 0' 7,800' Cmt w/ 1,150 sks of class G cmt 20 Excape modules placed Red control line fires top 9 modules contol line fires middle 8 modules Green control line fires bottom 3 modules Ceramic flapper valves below each module Module 20 - 6,119'-6,129' Module 19 - 6,196'- 6,206' Module 18 - 6,279'- 6,289' Module 17 - 6,444'- 6,454' Module 16 - 6,543'- 6,553' Module 15 - 6,681'- 6,691' Module 14 - 6,724'- 6,734' Module 13 - 6,781'- 6,791' Module 12 - 6,858'- 6,868' Module 11 - 7,084'- 7,094' Module 10 - 7,122'-7,132' Module 9 - 7,169'- 7,179' Module 8 - 7,240'- 7,250' Module 7 - 7,301'- 7,311' Module 6 - 7,379'- 7,389' Module 5 - 7,505'- 7,515' Module 4 - 7,791'- 7,801' Module 3 - 7,967'- 7,977' Module 2 - 8,102'- 8,112' Module 1 - 8,197'-8,207' TD PBTD 8,405' MD 8,324' MD 7,840' TVD 7,763' TVD Well Name & Number: Kenai Beluga Unit 33-6x Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): (TVD): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 1/912004 Completion Fluid: 6% KCL Prepared By: Kevin Skiba Last Revison Date: 7/3012008 KBU 33-6x Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11 W, S.M. ~ s Marathon Operations Summary Report MhG~ ,~.dil Con~arry Well Name: F(ENAI BELUGA UNIT 33-6X Daily Operations Re ort Date: 71A12008 Job Cate or R&M MAINTENANCE Edit a r may Install 'hew"tree cap. Install 318" Dynacoil g 7950' KB. 45D si. Foamer skid powered up and tubed. Begin injecting Foamer. Set Fluid Control ualue ~ Ph + 8trlTme B-dTme D~rthrs~ Opsaotle Acluaao tle 8b-is Ootlee aammenl Edit 08:00 0$:30 0.50 SAFETY NfTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSAands ecific 'ob hazards. Obtain SWP. 08:30 D9:46 1.25 RURD COIL AF Spat equipment. Lay down liners. RU Dynaaoil unit. Set fluid control valve ~ 380D psi( 74DD x 8.7 ppg ?4 .052= 3350 psi) +460 psi. 09:46 10:30 0.75 RURD COIL AF Stab coil in injector. Stab pack off. Pull test BHAto 65D lbs. 10:3D 11:00 0.50 RURD COIL AF Blow down tree cap. Swab leaks. Shut in well and flow line. Remove ree ca Install 'hew"tree ca . 11:00 11:3D D.50 TEST EQIP AF PTest tree cap to 2500 psi. Test good. 11:30 12:00 0.50 RURD COIL AF Carry injectorta well head and make up. 12:D0 14:30 2.50 RUNPUL COIL AF RIH (1) w13/8". Bring well back an. Running knuckle joint and centralizers far BHA Ta 6133' KB. Can't et below. POOH. 14:30 15:3D 1.00 RUNPUL COIL AF Remove knuckle joint. Running stiff BHAw/ centralizers. RIH (2)ta 7950' KB. 15:30 16:30 1.D0 RURD COIL AF At setting depth. Set slips. Gheak pack off. Begin pumping 24 gallons of foamer into coil. 16:30 17:30 1.00 KURD COIL AF Pumping complete. Disassemble injector and remoue coil. Set coil spool in well house. RD Dynacoil unit. Tube coil to foamer skid. Begin pumping foamer ~ .5 gpd. 17:30 18:OD D.50 SECURE WELL AF Secure well. Install placarding on valve. Install LOTO on Upper, lower master, and swab values. Tum in emit. Si n out and leaue loc. wvnv.pelaton.com Report Printed: 7r30I200$ ~, ~~ ,; • ,~ t ' ~ I v `.::.-~ ~ A,.6 ~ ` v "' ~ ~ SARAH PALIN, GOVERNOR ~+` Y. ~ .~ L9 E. ALASSA OII; A~R~~ ~`~ COrITSERVATIOI~T COI-IIrIISSIOIQ 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 Dennis Donovan FAX (907) 276-7542 Production Engineer Marathon Oil Comp (~~~ J Ud k~ 200$ PO Box 1949 Kenai AK 996 1 1-1 949 ~ ~ '3 ~d3! Re: Kenai Gas held, U pper 1~onek/Beluga Gas Pool, Kenai Beluga Unit 33-6x Sundry Number: 308-220 Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission shown, a person affected by it may file with the Commis of an application for rehearing. A request for rehearing is considered tunely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED ~~~ this -day of June, 2008 Encl. • M Marathon MARATHON Oil Company June 19, 2008 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Mr. Tom Maunder ~~ Alaska Oil & Gas Conservation Commission 333 W 7t" Ave ,SUN ~ 3 2008 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Cammi,siar3 A~ol,a','a0e Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 41-7 Well: Kenai Beluga Unit 33-6X (PTD 203-183) Dear Mr. Maunder: We propose to run a 3/8" capillary string in KBU 33-6X. With the availability of a capillary injection unit on the Peninsula starting the week of June 23rd 2008; we are able to mitigate water loading by running a capillary string and pumping foamers. Setting depth of the capillary string should be around 7950' MD. The past capillary string installation into KTU 24-6H (PTD 199-073) has yielded an approximate incremental gain of 475 MCFD over the past 3 months. We would like to continue to install capillary strings in other wells like KBU 33-6X and be able to realize longer and more stable production. Please find attached a 10-403, current wellbore diagram, and detailed operations program. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~~- Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File DMD KJS ~, ,~~ STATE OF ALASKA NN~ ~ ~ " y~ 6~-~''~~ O~ ."~ AL~ OIL AND GAS CONSERVATION COMA~1~bN ~ C.~ ~ APPLICATION FOR SUNDRY A~~?'~1f~~~o~ls. uosl~r~ i:~si-~n4~ 20 AAC 25.280 ~ r,c4~r;rar:~? 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate ^ Waiver ^ ther ^~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Install Capillary Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ String 2. Operator Name: Marathon OII Co111 an p y 4. Current Well Class: 5. Permit to Drill Number: Development Q Exploratory ^ 203-183 3. Address: p0 BOX 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-2052900-00=0@-- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ ~ Kenai Beluga Unit 33-6x Spacing Exception Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ILE~ M028083' 82' (21' AGL) Kenai Gas Field, Beluga 8~ Tyonek Pools 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8405' 7844' ~ 8324' " 7763' - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 139' 20" 139' 139' 3,060 1,500 Surface 1,512' 13-3/8" 1,512' 1,512' 3,450 1,950 Intermediate 5,752' 9-5/8" 5,752' 5,246' 6,870 4,750 Production 8,362' 3-1/2" 8,362' 7,801' 10,160 10,530 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,119'-8,207' 5,591'-7,647' N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program^ BOP Sketch ^ Exploratory ^ Development^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 28th, 2008 Oil ^ Gas 0 Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name D nnis M. Donovan Jr. Title Production Engineer Signature Phone (907) 283-1333 Date June 19th, 2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (~~ - ~ ~v Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~.~``, A d b APPROVED BY ~ n, ( COMMISSIONER THE COMMISSION Date: pprove U V 'vI a .~! ~F~_ ,~~lt~ ~ ~~~~ Form 10-403 Revised 06/2006 R ` ~ t ~ ~ L Submit in Duplicate 2008 Capillary String Installation Page 1 2008 Capillary String Installation Program CLU, SU, BC, KGF .and NGF WBS#s SD#3 - W0.08.18049.CAP.001 KBU 11-8Y, 33-6X, 41-7 - W0.08.18053.CAP.001 BC 13 - W0.08.18054.CAP.001 CLU 6 - W0.08.18056.CAP.001 SU 32-9 - W0.08.18117.CAP.001 GO 6 - W0.08.18196.CAP.001 Objective - Install a 3/8" Capillary String into these wells to alleviate liquid loading. We intend to treat the producing fluid level in each of these 8 wellbores with foamer. Install and Complete CICM (injection skids) to utilize on wellheads. We have seen an incremental increase on KTU 24-6H capillary string installation of approximately 475MCFD. Procedure Companies Evolved: UOSS, BJDC, BJCS, BigG • Installation Order ell Maximum Setting De th Maximum String Len th Minimum String Needed at Surface trin Size and T e lan a Connection Est'd Producing Fluid Level a De th Gauge Ring ID run Recommended Setting Depth From PT+Ta 1 CLU 6 8042' 8200' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 7880' 8058' 2.300" 8020' 2 SU 32-9 6200' 6250' 45' 2205 3/8" X 0.049" WT 3-1/8" 5M RX35 TBD TBD TBD TBD 3 BC 13 8590' 8750' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 7900' 10055' 2.300" 8580' 4 GO 6 10120' 10300' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 5 SD 3 9290' 9450' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 6 KBU 41-7 6910' 7050' 45' 2205 3/8" X 0.049" WT 3-1/$" 5M RX35 TBD TBD TBD TBD 7 KBU 11-8Y 8145' 8300' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 TBD TBD TBD TBD 8 KBU 33-6X 8200' 8350' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 TBD TBD TBD TBD 2008 Capillary String Installation Page 2 Installation Procedure: 1.) BJCS: (Hold PJSM and JSA) a) Complete placement of 3 new CICM skids on wells CLU 6, SD 3, and KBU 41-7, all other wells have units placed. They will complete Installation of items that are pertinent to operation of CICM. b) Move NS#3 CICM to GO#6 well 2.) UOSS: (Hold PJSM and JSA) a) Removal of all well houses to setup for BJ Dynacoil Unit b) Replacement of CICM roof on (3) new skids, after tanks are set inside containment. 3.) Big G: (Hold PJSM and JSA) a) Complete explosion proof electrical end fittings for CICM b) Complete tubing for hookup of Dynacoil - if needed. - Placement of an open conduit under the well house wall for easy routing of 3/8" id tubing for skid hookup. This will prevent multiple tubing disconnects when well work is needed, thus reducing exposure to trapped pressure. 4.) BJDC: 1. Hold PJSM and Complete JSA/JHA 2. Move in rig up BJ Dynacoil unit. 3. Replace tree-cap flange with specified internally threaded flange listed above in the matrix. 4. MU BHA and secure to 3/8" string. 5. MU WHA to internally threaded flange 6. MU Trailer Haskell Pump to WHA with 1" male NPT tie back assembly 7. Pressure test flange assembly against a closed valve to 1.5 times SITP with Trailer Haskell Pump. 8. "SHUT IN WELL AT WING VALVE" -This will prevent BHA from traveling down flowline. BHA is small and capable of flowing into flow-Tee 9. RIH with capillary below "Est'd Producing Fluid Level". All strings must be set into the producing fluid level to prove the most effective. 10. Set Rattiguns and Leave 1.5 times SITP or greater as requested by BJDC on hydraulic pack off. 11. "OPEN WELL TO PRODUCTION" 12. Leave remaining spool of tubing outside of well for soap injection skid hookup. 13. Cap the tubing with a Swagelok cap, Swagelok valve, and pressure gauge. 14. Lockout/Tagout Swab, Upper Master and Lower Master. (Install BJ Dynacoil signs on all valves stating "Do Not Operate BJ Dynacoil in wellhead". Proceed to Lockout valves with production lock and cable.) 15. Hookup injection line to CICM, and set specified rate for each well. 16. RDMO, Cleanup site, Sign-out Permit #: 203-183 API #: 50-133-20529-00-00 Prop. Des: A - 028083 KB Elevation: 82' (21' AGL) Latitude: Longitude: Spud: 12/13/2003 TD: 1 /2/2004 Rig Released: TOC (est.) - ???' Excaae Svstem Details - BHP monitoring line volume tank located from 6,055' - 6,093' - BHP monitoring line volume tank located from 6,055' - 6,093' - Ceramic flapper valves below each module as follows: Module 20 - 6,147.5' Module 19 - 6,223.8' Module 18 - 6,306.4' Module 17 - 6,470.9' Module 16 - 6,572.5' Module 15 - 6,709.5' Module 14 - 6,752.4' Module 13 - 6,809.3' Module 12 - 6,887.5' Module 11 - 7,110.3' Module 11 - 7,110.3' Module 10 - 7,149.3' Module 9 - 7,196.1' Module 8 - 7,266.3' Module 7 - 7,327.5' Module 6 - 7,407.7' Module 5 - 7,532.4' Module 4 - 7,822.2' Module 3 - 7,995.5' Module 2 - 8,131.5' Module 1 - NA • KBU 33-6x Pad 41-7 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. ~. M MARATNOM 20" K-55 133 ppf PE Top Bottom MD 0' 139' TVD 0' 139' 13-318" K-55 88 ppf BTC Top Bottom MD 0' 1,512' TVD 0' 1,512' Cmt w/ 320 sks 9-518" L-80 47 ppf BTC Top Bottom MD 0' 5,752' ND 0' 5,248' Cmt w1705 sks Class G 3-112" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 6,362' TVD 0' 7,800' Cmt wl 1,150 sks of class G cmt 20 Excape modules placed Green control line fires bottom 3 modules contol line fires middle 8 modules Red control line fires top 9 modules Ceramic flapper valves below each module Module 20 - 6,119'- 6,129' Module 19 - 6,196'- 6,206' Module 18 - 6,279'- 6,289' Module 17 - 6,444'- 6,454' Module 16 - 6,543'- 6,553' Module 15 - 6,681'- 6,691' Module 14 - 6,724'- 6,734' Module 13 - 6,781'- 6,791' Module 12 - 6,858'- 6,868' Module 11 - 7,084'- 7,094' Module 10 - 7,122'- 7,132' Module 9 - 7,169'-7,179' Module 8 - 7,240'- 7,250' Module 7 - 7,301'- 7,311' Module 6 - 7,379'- 7,389' Module 5 - 7,505'- 7,515' Module 4 - 7,791'- 7,801' Module 3 - 7,967'- 7,977' Module 2 - 8,102'-8,112' Module 1 - 8,197'- 8,207' TD PBTD 8,405' MD 8,324' MD 7,840' TVD 7,763' TVD Well Name & Number: Kenai Beluga Unit 33-6x Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): (TVD): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 1/9/2004 Completion Fluid: 6% KCL Prepared By: Kevin Skiba Last Revison Date: 6/19/2008 in /J •perations Summary Report by J. Marathon Oil Well Name: KENAI BELUGA UNIT 33 -6X 7 7 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State/Province Country Sec.6, T4N, R11W, S.M. KENAI ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 20.12 25.121 5.00 12/13/2003 1/9/2004 Daily Operations Report Date: 1/22/2004 Job Category: COMPLETION 24 Hr Summary Rig up Reeves Wireline and ran Sonic bond log from 8250' KB to top of cement at 4520'. Ops Trouble - - Start Time End Time Dur (hr) Ops Code - Activity Code Status Code Com 09:00 10:00 1.00 RURD SLIK AF RU Reeves WL. Make up sheeve to Boom truck for running in well. MU vac truck to flow line to pull any displacement fluid while running in well with tools. 10:00 14:30 4.50 LOG CSG AF No pressure test, discussed safety and envrionmental issues. RIH with sonic tool string. Pulled repeat section from 4150 through 4510' KB. Made log from 8250' KB to top of cement at 4520' KB. POOH with tool string. 14:30 15:30 1.00 LOG CSG AF Down loaded data and e- mailed to Anchorage Engineering to verify log is good. Log good continue to RD unit. Released boom truck and vac truck. 15:30 16:00 0.50 RURD SLIK AF Cleaned up around well head, secured well and left lease. Report Date: 2/1/2004 Job Category: COMPLETION 24 Hr Summary Held PJSM. Fracture stimulate modules 1 through 7. Ran out of crosslink chemical. Trouble shoot crosslinking chemical delivery system. RIH with coil tubing and cleanout well. Jet well in and turn well to production for cleanup. Wait on crosslinker. - - - _ Ops Trouble- - Start Time End Time Dur (hr) Ops Code • Activity Code Status Code . Com • 05:30 06:00 0.50 SAFETY SMTG AF Held pre -frac safety meeting prior to commencing Excape stimulations. ( Perforated module 1(8198 -8208) with Expro personnel on 1/27/2004 with 3050 psi surface pressure on green line.) (1/27 through 1/31 - Rigged up location and frac equipment, built frac fluid volumes, and pressure tested lines to 8600 psi) 06:00 08:30 2.50 RURD EQIP AF Prepare BJ frac equipment, load chemical pumps with required chemicals for fracture stimulation treatments. 08:30 09:30 1.00 PUMP FRAC AF Treat module 1 perfs (8198- 8208). Pumped 12 bbls of pad and then pressured up rapidly. Would not bleed off. Bleed lines to clean up tank. Verify all surface lines and valves open. Flow well to clean up tank for 10 minutes. Begin treatment again. Pumped 71 bbls pad follwed by 22 bbls of 2 ppa when pressures started to rise prematurely. Went to flush and displaced all of 2 ppa volume into perfs. Place 2000 Ibs proppant in perfs ( 1750 ibs 20/40 ottawa and 250 Ibs 20/40 flex sand) 09:30 10:00 0.50 PUMP FRAC AF Perforated module 2 (8104 -8114) Pumped total of 272 bbls of frac volumes, ramping proppant from 2 -8 pg. Placed 31000 Ibs of proppant in perfs (27100 of 20/40 ottawa and 3900 of 20/40 flex sand) 10:00 11:00 1.00 PUMP FRAC AF Perforated module 3 (7968 -7978) Pumped total of 270 bbls of frac volumes, ramping proppant from 2 -8 ppg. Placed 31000 Ibs of proppant in perfs (27100 of 20/40 ottawa and 3900 of 20/40 flex sand) 11:00 11:30 0.50 PUMP FRAC AF Perforated module 4 (7792 -7802) Pumped total of 286 bbls of frac volumes, ramping proppant from 2 -8 ppg. Placed 35000 Ibs of proppant in perfs (30600 of 20/40 Ottawa and 4400 of 20/40 flex sand) 11:30 12:00 0.50 PUMP FRAC AF Perforated module 5 (7504 -7514) Pumped total of 266 bbls of frac volumes, ramping proppant from 2 -8 ppg. Placed 31400 Ibs of proppant in perfs (27500 of 20/40 ottawa and 3900 of 20/40 flex sand) 12:00 12:30 0.50 PUMP FRAC AF Perforated module 6 (7380 -7390) Pumped total of 265 bbls of frac volumes, ramping proppant from 2 -8 ppg. Placed 31400 Ibs of proppant in perfs (27500 of 20/40 ottawa and 3900 of 20/40 flex sand) 12:30 13:00 0.50 PUMP FRAC TA MSSM Toubleshoot frac truck. Same frozen up. Thaw out and put back into operation 13:00 13:30 0.50 PUMP FRAC TA MSSM Perforated module 7 (7300 -7310) Pumped total of 271 bbls of frac volumes, 2 ramping proppant from 2 -8 ppg. Placed 33000 Ibs of proppant in perfs JU 1 1U1 (28900 of 20/40 Ottawa and 4100 of 20/40 flex sand). During treatment, noticed wurface pressure decrease during 8 ppg stage and flush volume without any decrease in BHP, indicating fluid compostion change. Inspect all chemical tanks and found that crosslinker chemical tank was empty. Estimated that modules 3 through 7 were over crosslinked. No more crosslinker available in state. 13:30 16:30 3.00 WAITON WTHR TA MSSM Wait on Orders (Place order for more corsslinker to be air freighted from lower 48) 16:30 18:30 2.00 RURD COIL TA MSSM Prepare coilt tubing and equipment to RIH and clean out module 1 -7 frac treaments. Held PJSM. Retested lines to 4500 psi. www.peloton.com Page 1/6 Report Printed: 8/3/2011 • It4W •perations Summary Report by JO Marathon oil Well Name: KENAI BELUGA UNIT 33 -6X Qtr /Qtr, Block, Sec, Town, Range Field Name I License # State /Province Country Sec.6, T4N, R11W, S.M. 'KENAI ALASKA USA Casing Flange Elevaton (m) Elevation (m) Ground KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 20.12 25.121 5.00 12/13/2003 1/9/2004 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 18:30 23:30 5.00 TRIP BHA TA MSSM Run in Hole with Coiled Tubing. Bust excape module flappers at 7318' and 7398'. No otherindications of busting remainingfour flappers. Wash to PBTD of 8300' with full returns. POOH to module 7 and RIH attempting to see remaining flappers without success. POOH to 1600'. 23:30 06:00 6.50 PUMP N2 TA MSSM Begin N2 Lifting / Well Unloading with N2 at 1600'. RIH to 4000' jetting well in with N2. Started taking flowback samples after tubing load recovered. Well began flowing. POOH with coil tubing. Shut well in with initial SITP = 500 psig. R/D coil tubing and secure equipment. Turn well over to production for flowback and cleanup of modules 1 -7. Report Date: 2/6/2004 Job Category: COMPLETION 24 Hr Summary Perform Escape frac treatments on Modules 8 thru 20. Rig up C/T, clean out well and jet in with N2. Flow well to Clean -up through gas buster. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 05:30 06:00 0.50 PUMP FRAC TA MSSM Held pre -frac safety meeting at KGF prior to commencing Escape stimulation. 06:00 08:30 2.50 PUMP FRAC TA MSSM Arrive location. Well making 2.85 MMCFD @ 1265 psi FTP w/ 42 BWPD. Prep for Escape frac operations. Secure well and test lines. 08:30 09:00 0.50 PUMP FRAC TA MSSM Open Well. SITP = 1982 psi. Load hole with cross - linked gel. 09:00 09:30 0.50 PUMP FRAC AF Fire Expro gun mod No.8 with 7500 psi perf interval 7,240' - 7,250' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 4000 psi. Ramp 2.0 - 8.0 ppa. Place 32,180 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 319 bbl. Tagged w/ ProTechnics CFT 1600. 09:30 10:00 0.50 PUMP FRAC AF Fire Expro gun mod No.9 with 8350 psi pert interval 7,169' - 7,179' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 4300 psi. Ramp 2.0 - 8.0 ppa. Place 31,722 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 236 bbl. Tagged w/ Protechnics CFT 1700. 10:00 10:30 0.50 PUMP FRAC AF Fire Expro gun module No.10 with 9000 psi pert interval 7,122' - 7,132' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 3900 psi. Ramp 2.0 - 8.0 ppa. Place 30.772 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 226 bbl. Tagged w/ Protechnics CFT 1700. 10:30 11:00 0.50 PUMP FRAC AF Fire Expro gun module No.11 with 9500 psi perf interval 7,084' - 7,094' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 3500 psi. Ramp 2.0 - 8.0 ppa. Place 28,564 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 225 bbl. Tagged w/ Protechnics CFT 1900. 11:00 11:30 0.50 PUMP FRAC AF Fire Expro gun module No.12 with 2700 psi perf interval 6,858' - 6,868' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 3700 psi. Ramp 2.0 - 8.0 ppa. Place 29,873 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 225 bbl. Tagged w/ Protechnics CFT 2000. 11:30 12:00 0.50 PUMP FRAC AF Fire Expro gun module No.13 with 3700 psi pert interval 6,781' - 6,791' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 3000 psi. Ramp 2.0 - 8.0 ppa. Place 27,230 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 215 bbl. No chem tracers. 12:00 13:00 1.00 PUMP FRAC AF Fire Expro gun module No.14 with 4500 psi perf interval 6,724' - 6,734' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 3000 psi. Ramp 2.0 - 8.0 ppa. Place 27,623 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 215 bbl. No chem tracers. 13:00 13:30 0.50 PUMP FRAC AF Fire Expro gun module No.15 with 5800 psi perf interval 6,681' - 6,691' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 3000 psi. Ramp 2.0 - 8.0 ppa. Place 27,247 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 219 bbl. Tagged w/ Protechnics CFT 2100. 13:30 14:00 0.50 PUMP FRAC AF Fire Expro gun module No.16 with 6540 psi perf interval 6,543' - 6,553' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 2800 psi. Ramp 2.0 - 8.0 ppa. Place 31,196 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 226 bbl. Tagged w/ Protechnics CFT 2200. www.peloton.com Page 2/6 Report Printed: 8/3/2011 • •Operations Summary Report by Je Marathon oil Well Name: KENAI BELUGA UNIT 33 -6X Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country Sec.6, T4N, R11W, S.M. KENAI ALASKA USA Casing Flange Elevation (m) KB- Casing Flange Distance Ground Elevation (m) (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.001 20.12 25.12 5.00 12/13/2003 1/9/2004 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 14:00 14:30 0.50 PUMP FRAC AF Fire Expro gun module No.'17 with 7850 psi perf interval 6,444' - 6,454' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 3000 psi. Ramp 2.0 - 8.0 ppa. Place 31,608 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 220 bbl. Tagged w/ Protechnics CFT 2200. 14:30 15:00 0.50 PUMP FRAC AF Fire Expro gun module No.'l8 with 8780 psi perf interval 6,279' - 6,289' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 3500 psi. Ramp 2.0 - 8.0 ppa. Place 27,157 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 210 bbl. No chem tracers. 15:00 15:30 0.50 PUMP FRAC AF Fire Expro gun module No.19 with 9750 psi perf interval 6,196' - 6,206' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 2500 psi. Ramp 2.0 - 8.0 ppa. Place 28,050 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 210 bbl. Taged w/ Protechnics 2400. 15:30 16:00 0.50 PUMP FRAC AF Fire Expro gun module No.20 with 10700 psi perf interval 6,119' - 6,129' MD. Frac w/ BJ Lightning_25_180 wtr based gel at 15 BPM at max TP = 2500 psi. Ramp 2.0 - 8.0 ppa. Place 54,062 Ibs prop (87.5 % 16/30 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 256 bbl. Tagged w/ Protechnics 2500. Total Sand Placed Mod 8 - 20 = 407,269 Ibs Total Load Water Mod 8 - 20 = 3002 bbls All Pad Stages Tagged w/ Protechnics Sc-46. All Prop Stages Tagged w/ Protechnics Ir -192. 16:00 18:00 2.00 PUMP FRAC AF RD Frac Equipment and Expro Perforators. 18:00 20:00 2.00 PUMP N2 AF RU BJ Coil Tech Coil Tubing & Nitrogen Unit. Lift and stab injector head and test. 20:00 02:00 6.00 PUMP N2 AF RIH w/ 1 -3/4 "" CT and chisel wash tool. Wash to TD @ 8300' CTM looking for Escape flapper valves. Only indication of a flapper tag was at modules 18, 3 & 4. No other flapper valves were tagged in the well. Circ BU till clean. 02:00 04:00 2.00 PUMP N2 AF POOH to 6000'. Jet well w/ 1000 scf /m N2 to 3000'. Cut N2 and POOH. Flow well to gas buster while jetting. 04:00 06:00 2.00 PUMP N2 AF RD BJ CT injector head. Continue to flow well to clean -up frac fluids through gas buster. Report Date: 2/7/2004 Job Category: COMPLETION 24 Hr Summary Well Clean -up operations. Flow well to clean -up through gas buster, sand buster and Halliburton test spread. Ops Trouble Start Time . - End Time , Dur (ht) Ops Code Activity Code _ Status Code Com 06:00 06:30 0.50 FLOW TEST AF Clean -up flow back operations following Escape Frac of Beluga/Tyonek zones. Cont to flow well through gas buster. Divert flow to Halliburton test spread. Could not dump water. Divert flow to sand buster. Plugged sand buster. 06:30 14:00 7.50 FLOW TEST AF Break down and clean out sand buster. 14:00 17:00 3.00 FLOW TEST AF SITP ini = 1700 psi. Flow well to gas buster to unload. 17:00 17:30 0.50 FLOW TEST AF Divert flow well to sand buster and Halliburton test spread: 0000: 410 mcfd, 550 psi FTP, 16/64 " ", 188 BW cum 17:30 22:30 5.00 REPAIR EQIP TA MSFB Sand Buster plugged. Work to unplug sand buster. 22:30 06:00 7.50 FLOW TEST AF SITP ini = 1500 psi. Cont flow well to sand buster and Halliburton test spread: 0100: Min Gas, Variable Chk, 297 BWPD, 196 BW cum 0200: Min Gas, Variable Chk, 593 BWPD, 213 BW cum 0300: Min Gas, Variable Chk, 847 BWPD, 243 BW cum 0400: Min Gas, Variable Chk, 593 BWPD, 266 BW cum 0500: Min Gas, Variable chk, 422 BWPD, 282 BW cum Report Date: 2/8/2004 Job Category: COMPLETION 24 Hr Summary Well Clean -up operations. Flow well to clean -up. Well loaded and died. www.peloton.com Page 3/6 Report Printed: 8/3/2011 fi . itl. • Casing & Cement • ?np ze 3_tr3 Marathonoil Well Name: KENAI BELUGA UNIT 33 -6X For String: SURFACE CASING Casing Detail: Casing Description Prop Run? - Run Date Set Depth (mKB) Set Tension (tonnef) Wellbore Centralizers Scratchers SURFACE CASING No 12/15/2003 00:00 460.87 0.0 KENAI BELUGA UNIT 33 -6X Comment August 9, 2004 This is a revision of the original report giving the estimated string configuration, as the original report showed the string set at 1552.5' when the hole was only 1518'. There is confidence in the setting depth of 1512'. The two values which cannot be verified are the distance from the top of the casing hanger to RKB and the length of the joint which was cut off at the top. (BAC) DFW String Key = IWHBI Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING HEAD Casing 346.1 346.1 FLANGE 0.53 6.13 6.65 UPPER BOWL (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg/m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING HEAD Casing 346.1 314.3 FLANGE 0.59 6.65 7.24 ThreadLock Y /N: N LOWER BOWL (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CUT -OFF JOINT Casing 339.7 315.3 101.195 K -55 BTC 4.36 7.24 11.59 ThreadLock Y /N: N (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 35 CASING JOINT(S) Casing 339.7 315.3 101.195 K -55 BTC 435.78 11.59 447.38 ThreadLock Y /N: N (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 STAB -IN FLOAT Casing 339.7 315.3 N -80 BTC 0.57 447.38 447.95 ThreadLock Y /N: Y COLLAR (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING JOINT(S) Casing 339.7 315.3 101.195 K -55 BTC 12.40 447.95 460.35 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 FLOAT SHOE Casing 339.7 315.3 N -80 BTC 0.52 460.35 460.87 ThreadLock Y /N: Y shoe Cementing Job Details:.. Cementing Start Date Cementing End Date Cementing Company 12/15/2003 00:00 I B.J. SERVICES Comment BHT logged (Y /N): N Cement Found on Between Chow and Collar (Y /N): Y Cement found on liner tool (Y /N): N Coil tubing unit indicator: N Tool company: Stab -In Collar /Float Shoe Wait on cement (hrs): 12 Description Type String Wellbore SURFACE CASING ' Casing ' SURFACE CASING, 460.87mKB KENAI BELUGA UNIT 33 -6X Cement.Stage #1, Description: . . . Float Failed? Plug Failed? Full Retum? Pipe Reciprocated? Pipe Rotated? Pressure Held (kPa) No I Yes Yes No ' No Stage Number Top Depth (mKB) Bottom Depth (mKB) Cement Volume Retum (m') 1 0.00 461.16 3.97 Top Plug? Bottom Plug? Final Pump Rate (m'/min) Pump Start Time Pump End Time Yes ' No 'Initial Pump Rate (m' /min) 0.795 I ' Avg Pump Rate (m' /min) 'Drill Out Dia (mm) 'Final Pump Pressure (kPa) 'Plug Bump Pressure (kPa) 'Pressure Release Date 0.795 0.0 Comment Annular flow after cement job (Y /N): N Hours circulated between stages: 0.5 Pressure before cementing: 620 Excess volume measured from: Calculated Returns: Full retums Time cementing mixing started: 15:50 www.peloton.com Page 1/2 Report Printed: 8/3/2011 /j' ill • Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 33 -6X For String: SURFACE CASING Cement Fluids TURBULENT SPACER Class Density (kg /m') Yield (m'/tonne) Volume Pumped (m') OTHER 1,006.5 6.36 Comment Displacement fluid used: MUD Time displacement started: : Wait on Cement Time: 12 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 40 Fluid Type 'Amount (1000kg) 'Mix H2O Ratio (m'/tonne) 'Percent Excess Pumped ( %) TURBULENT SPACER 1 50.0 Cement Fluid Additives Add Amount Amount Units - Conc Unit Conc Type MUDCLEAN II 1,680.0 GAL SAPP TAIL Class Yield (monne) Volume Pumped (m') TYPE I 'Density (kg /m') '/t 1,437.91 1.5671 22.74 Comment Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 90 Free water test temperature: 90 Total water used: 39 Fluid loss test pressure: 1000 Thickening test pressure: 90 Fluid Type Mix H2O Ratio (m'ftonne) Percent Excess Pumped ( %) TAIL 'Amount (1000kg) 14.51 0.941 50.0 Cement Fluid Additives "Add - - . Amount - - Amount Units. - - Conc Unit Cone Type CD-32 0.3 % BWOC FP -6L 1.0 gal /100sx Fresh Water 100.1 % BWOC LW-6 18.0 % BWOC MPA -1 20.0 % BWOC Sodium Metasilicate 1.0 % BWOC wellheads Install Date 'Type 'Job 'Removed Date 'Comment www.peloton.com Page 2/2 Report Printed: 8/3/2011 di-Aw , Casing & Cement • IKT) o2 _ 1ti Marathon Oil Well Name: KENAI BELUGA UNIT 33 -6X 2 For String: INTERMEDIATE CASING Casing Detail: Casing Description Prop Run? Run Date Set Depth (mKB) Set Tension (tonnef) Wellbore Centralizers Scratchers INTERMEDIATE CASING No 12/28/2003 00:00 1,753.28 0.0 KENAI BELUGA UNIT 33 -6X Comment Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING HANGER Casing 244.5 224.3 Acme 0.21 5.46 5.67 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING HANGER Casing 342.9 224.3 0.11 5.67 5.78 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING HANGER Casing 269.9 224.3 Butt 0.13 5.78 5.91 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 PUP JOINT Casing 244.5 220.5 69.944 Butt 0.97 5.91 6.87 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 13 CASING JOINT(S) Casing 244.5 220.5 69.944 L -80 Butt 1,720.46 6.87 1,727.34 7 (black) MOD Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING FLOAT Casing 244.5 Butt 0.45 1,727.34 1,727.78 ThreadLock Y /N: Y COLLAR (black) Jts ' Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 CASING JOINT(S) Casing 244.5 220.5 69.944 L -80 Butt 24.98 1,727.78 1,752.76 ThreadLock Y /N: Y (black) MOD Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING FLOAT Casing 244.5 Butt 0.52 1,752.76 1,753.28 ThreadLock Y /N: Y SHOE shoe Cementing. Job. Details:. , . Cementing Start Date I Cementing End Date Cementing Company 12/30/2003 00:00 I B.J. SERVICES Comment BHT logged (Y /N): N Cement Found on Between Chow and Collar (Y /N): N Cement found on liner tool (Y /N): N Coil tubing unit indicator: N Description Type String Wellbore INTERMEDIATE CASING Casing INTERMEDIATE CASING, KENAI BELUGA UNIT 33-6X 1,753.28mKB Ce Descnptio� : - . . 'Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pipe Rotated? Pressure Held (kPa) No f No Yes No No Stage Number Top Depth (mKB) Bottom Depth (mKB) Cement Volume Retum (m') 1 944.88 16,993.21 Top Plug? !Bottom Plug? !Initial Pump Rate (m' /min) 'Final Pump Rate (m' /min) !Pump Start Time (Pump End Time Yes Yes 0.954 Avg Pump Rate (m' /min) !Drill Out Dia (mm) !Final Pump Pressure (kPa) !Plug Bump Pressure (kPa) !Pressure Release Date 0.954 5,515.8 8,963.2 Comment Annular flow after cement job (Y /N): N Hours circulated between stages: 1.5 Pressure before cementing: 231 Excess volume measured from: Gauge hole Returns: 100% Time cementing mixing started: 16:30 www.peloton.com Page 1/2 Report Printed: 8/3/2011 /J • Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 33 - 6X For String: INTERMEDIATE CASING 'Cement Fluids TAIL Class Density (kg /m') Yield (m'ttonne) Volume Pumped (m') CLASS G 1,617.7 1.155 36.89 Comment Displacement fluid used: MUD Time displacement started: : Wait on Cement Time: 0 Compressive strength temp #2: 110 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 98 Free water test temperature: 98 Total water used: 156 Fluid loss test pressure: 3000 Thickening test pressure: 3000 Fluid Type Mix H2O Ratio (monne) Percent Excess Pumped ( %) TAIL 'Amount (1000kg) 32.01 0.781 50.0 Cement Fluid Additives Add Amount - Amount Units Cone Unit Cone Type ASA -301 0.1 % BWOC BA -56 2.5 % BWOC BA -90 10.0 % BWOC CALC2 3.0 % BWOC FP -6L 1.0 gphs SMS 0.5 % BWOC Wellheads . Install Date (Type 'Job 'Removed Date 'Comment www.peloton.com Page 2/2 Report Printed: 8/3/2011 • &Ali • Casing & Cement • �` Marathon Oil Well Name: KENAI BELUGA UNIT 33 -6 C� 'S IICS For String: PRODUCTION CASING #1 Casing Detail: Casing Descnption Prop Run? Run Date Set Depth (mKB) Set Tension (tonnes) Wellbore Centralizers Scratchers PRODUCTION CASING #1 No 1/7/2004 00:00 2,548.62 0.0 KENAI BELUGA UNIT 33 -6X Comment KBU 33- 6XWBD.xls on the network says that distance RT - THE is 16.8' DFW String Key = TB530 Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 PUP JOINT Casing 88.9 76.0 13.840 L -80 BTC 3.04 -1.38 1.66 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 PARTIAL JOINT Casing 88.9 76.0 13.840 L -80 BTC 9.55 1.66 11.21 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 19 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 1,834.47 11.21 1,845.68 2 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.52 1,845.68 1,857.20 PRESSURE (black) MODULE Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 6.08 1,857.20 1,863.28 ASSEMBLY (black) Jts Item Description Icon OD (mm) ' ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.84 1,863.28 1,875.11 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mK8) Btm (mKB) Comment 1 PUP JOINT Casing 88.9 76.0 13.840 L -80 BTC 1.86 1,875.11 1,876.98 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 9.56 1,876.98 1,886.53 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.86 1,886.53 1,898.39 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 3.78 1,898.39 1,902.17 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 9.56 1,902.17 1,911.73 (black) Jts Item Descnption Icon OD (mm) ID (mm) Wt (kg/m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.90 1,911.73 1,923.63 MODULES (black) Jts Item Description Icon 0D (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 4 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 38.23 1,923.63 1,961.87 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.83 1,961.87 1,973.70 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg/m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 19.12 1,973.70 1,992.82 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.83 1,992.82 2,004.65 MODULES (black) • Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 1.24 2,004.65 2,005.89 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 28.70 2,005.89 2,034.59 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.80 2,034.59 2,046.38 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 1.28 2,046.38 2,047.66 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.80 2,047.66 2,059.46 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 5.53 2,059.46 2,064.98 ASSEMBLY (black) www.peloton.com Page 1/4 Report Printed: 8/3/2011 iii .W • • Casing & Cement i Marathon Well Name: KENAI BELUGA UNIT 33 -6 V For String: PRODUCTION CASING #1 Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.84 2,064.98 2,076.83 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 2.42 2,076.83 2,079.24 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 9.56 2,079.24 2,088.81 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.85 2,088.81 2,100.65 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 4 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 8.28 2,100.65 2,108.93 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 5 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 47.81 2,108.93 2,156.74 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.84 2,156.74 2,168.58 MODULES (black) Jts Item Description 'Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.87 2,168.58 2,180.44 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 2.41 2,180.44 2,182.85 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.94 2,182.85 2,194.79 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg/m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 9.55 2,194.79 2,204.34 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.80 2,204.34 2,216.14 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 6.78 2,216.14 2,222.92 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.86 2,222.92 2,234.78 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 3.04 2,234.78 2,237.82 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 9.54 2,237.82 2,247.36 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.86 2,247.36 2,259.22 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 7.07 2,259.22 2,266.29 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 19.13 2,266.29 2,285.42 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.80 2,285.42 2,297.21 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread ' Length (m) Top (mKB) Btm (mKB) Comment 8 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 76.48 2,297.21 2,373.70 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.83 2,373.70 2,385.53 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 3.05 2,385.53 2,388.58 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 4 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 37.94 2,388.58 2,426.52 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.82 2,426.52 2,438.33 MODULES (black) www.peloton.com Page 2/4 Report Printed: 8/3/2011 I • /j W • Casing & Cement e Marathon Oil Well Name: KENAI BELUGA UNIT 33 -6 For String: PRODUCTION CASING #1 Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 1.01 2,438.33 2,439.34 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 28.67 2,439.34 2,468.01 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.79 2,468.01 2,479.80 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 EXCAPE PUP Casing 88.9 76.0 13.840 L -80 BTC 7.80 2,479.80 2,487.60 ASSEMBLY (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 9.56 2,487.60 2,497.16 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 EXCAPE Casing 88.9 76.0 N -80 BTC 11.52 2,497.16 2,508.68 MODULES (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 28.69 2,508.68 2,537.38 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING FLOAT Casing 88.9 76.0 N -80 BTC 0.20 2,537.38 2,537.58 COLLAR (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING JOINT(S) Casing 88.9 76.0 13.840 L -80 BTC 9.57 2,537.58 2,547.15 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 PUP JOINT Casing 88.9 76.0 13.840 L -80 BTC 1.29 2,547.15 2,548.44 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING FLOAT Casing 88.9 76.0 N -80 BTC 0.18 2,548.44 2,548.62 SHOE shoe Cementing Job Details: . Cementing Start Date Cementing End Date Cementing Company 1/8/2004 00:00 l B.J. SERVICES Comment Coil tubing unit indicator: N Tool company: POSITIVE Wait on cement (hrs): 8 Description Type String Welibore PRODUCTION CASING Casing PRODUCTION CASING #1, KENAI BELUGA UNIT 33 -6X 2,548.62mKB Cemeit$tage #9 Description:;. .. - . . . „ . ' Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pipe Rotated? Pressure Held (kPa) No ` No Yes Yes l No Stage Number Top Depth (mKB) Bottom Depth (mKB) Cement Volume Return (m') 1 1,422.81 2,548.74 Top Plug? Bottom Plug? Initial Pump Rate (m' /min) Final Pump Rate (m' /min) Pump Start Time Pump End Time Yes No J 0.795 I Avg Pump Rate (m' /min) 'Drill Out Dia (mm) Final Pump Pressure (kPa) Plug Bump Pressure (kPa) Pressure Release Date 0.7151 14,479.0 22,063.2 Comment PIPE MOVEMENT NOTES: Drag down 70000 Drag up 102000 Pipe movement: RECIPROCATING Time stopped reciprocating: 08:30 Time started reciprocating: 04:00 Annular flow after cement job (Y /N): N Circulating BHT: 130 Static BHT: 120 Hours circulated between stages: 5.5 Pressure before cementing: 900 Excess volume measured from: CALIPER Returns: FULL MUD RETURN Time cementing mixing started: 07:50 www.peloton.com Page 3/4 Report Printed: 8/3/2011 t jAw .. • Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 33 -6X For String: PRODUCTION CASING #1 Cement Fluids WEIGHTED SPACER Class Density (kg /m') Yield (m'/tonne) Volume Pumped (m') 1,378.0 7.95 Comment Displacement fluid used: BRINE Time displacement started: : Wait on Cement Time: 8 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 50 Fluid Type Amount (1000kg) Mix H2O Ratio (m'/tonne) Percent Excess Pumped ( %) WEIGHTED SPACER 35.0 Cement Fluid Additives Add Amount Amount Units Conc Unit Conc Type Barite 90.0 Ibs /bbl Bentonite 30.15 lbs/bbl KCI 9.0 Ibs /bbl MCS -4D 50.0 bbls MCS -D 6.0 Ibs /bbl TAIL Class Yield (m'/tonne) Volume Pumped (m') CLASS G 'Density (kg /m') 1,893.3 0.7181 36.57 Comment Compressive strength temp #2: 137 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 120 Free water test temperature: 120 Total water used: 145 Fluid loss test pressure: 100 Thickening test pressure: 1000 Fluid Type 1 Amount (1000kg) Mix 1120 Ratio (mMonne) Percent Excess Pumped ( %) TAIL 52.2 0.411 35.0 Cement Fluid Additives - Add - Amount • . Amount Units Conc Unit Conc Type Gas Migration Add 1.2 % BWOC BA -56 Defoamer 1.0 ga1/100sx FP -6L 0.05 % BWOC R -3 Sodium Metasilicate 0.2 % BWOC SMS Wellheads . Install Date 'Type rob (Removed Date 'Comment www.peloton.com Page 4/4 Report Printed: 8/3/2011 ,M MARATHON 4 . Marattion Oil Company . Alaska Asset Team Northern Business Unit P.O. Box 196168 Anchorage, AK 99519-6188 Telephone 907-565-3044 Fax 907-565-3076 June 8, 2006 Attention: Howard Oakland Alaska Oil & Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 Federal Express RE: Marathon KBU 33-6X Well Data API 50-133-20529-00 CONFIDENTIAL Dear Howard: Enclosed are the following CONFIDENTIAL digital data for the KBU 33-6X well: KBU 33-6X Directional Survey ¡g¡ kbu_33-6x_dir _aogcc.dat Formation Tops 1m kbu_33-6x_trm_ tops _aogcc.dat :# ) ] c¿ L{)~ Log Data l!J KBU 33-6X FINAL.las [il<)KBu 33-6X FINAL1VD,las [iI<) kbu_33-6x_reevesJeprocess.las ðkbu_33-6x_field.dpk Please indicate your receipt of this data by signing below and returning one copy to me at the letterhead address or fax to 713-499-8504. Thank you, '--. Enclosures Received by' ()JLJ Of J~ a ~òh Date: ;{D~-fð~ <;-~~~ DATA SUBMITTAL COMPLIANCE REPORT 6/7/2006 Permit to Drill 2031830 Well Name/No. KENAI BELUGA UNIT 33-06X Operator MARATHON OIL CO AP~'~~13~-:05t~: () ~) MD 8405._ TVD 7844 /' Completion Date 2/5/2004 ~ Completion Status 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional SUNey Yes I~ ð INt; DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: SP/GR-IEL-Density/Neutron-Sonic-single Arm Caliper (data taken from Logs Portion of Master Well Data Maint Log/ Data Type I Electr Digital Dataset Med/Frmt Number Name Log Log Scale Media Run No Interval OH / Start Stop CH Received Comments . Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? (JJ/N Y® Chips Received? ~ Formation Tops Analysis Received? Y'f.w Comments: S&.c.. ~tf....M -t.~:l CI-~J- ...... - _. -" ~~ . Compliance Reviewed By: ~ -"--~-~ Date: ì J~ ~ ~ Kaynell, I guess that summer has arrived. Freezing temps in Fairbanks, but that's Fairbanks. Kenai Beluga Unit 33-6X (API 50-133-20529-00) is missing some data. Formation tops were not reported on the completion report. A separate sheet with the formations and depths would be great. Open hole logging data (Completion reports says that SP/GR-IEL-Density/Neutron-Sonic-Single Arm Caliper logs were run.) Logging digital files Blue lines Reproduceables Directional survey in digital form (ascii text Measured Depth, Inclination angle and Azimuth) Thanks Howard . . Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Marathon Oil Company May 12, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡lh Ave, Suite 100 Anchorage, AK 99501 RECEIVED JUN 0 7 2006 Reference: Completion Report 10-407 for permit 203-183 Field: Kenai Gas Field / Beluga & Tyonek Well: KBU 33-6X Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Aubert, Enclosed please find the Well Completion Report with associated attachments for Kenai Gas Field well KBU 33-6X. This well has been completed cased hole with a 3.5" Excape monobore production string to surface. I apologize for the delay in getting this completion notice to you. Should you require further information, I can be reached at 907-529-0524 / 713-296- 2730, or bye-mail atJRThompson@MarathonOil.com. ; .~ r Sincerely, çr:~=- Sr. Completions Engineer Enclosures: Completion Report Directional Survey Operations Summary Wellbore Diagram Kt:l.,;t:I VI;:I.JI . STATE OF ALASKA" JUN 0 7 2006 ALASKML AND GAS CONSERVATION COMMIS~N WELL COMPLETION OR RECOMPLETION REPORT AND t!.èOJiI & Gas Cons. Commissior Anch nage Exploratory [[] o 1a. Well Status: OilO PlU9gedOAbandoned 0 20AAC 25.105 Suspended 0 WAGO 20AAC 25,110 Gas~ GINJ o WINJD No. of Completions Other WDSPLO 2. Operator: Name: Marathon Oil Company 5. Date Comp., Susp., or Aband: 2/5/2004 3 Address: 6. Date Spudded: P.O. Box 196168, Anchorage, AK 99519-6168 12/13/2003 4a. Location of Well (Governmental Section): 7. Date TD Reached: 1/2/2004 Surface: 42' FSL, 860' FEL, Sec. 6, T4N, R11W, S.M. 8. KB Elevation (ft.): 82 9. Plug Back Depth (MD + TVD): Top of Productive Horizon: 1,672' FSL, 1,779' FEL, Sec. 6, T4N, R11W, S.M. 8324' MD / 7763' TVD Total Depth: 2,051' FSL, 2,019' FEL, Sec. 6, T4N, R11W, S.M. 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD): 8405' MD / 7844' TVD 11. Depth where SSSV Set: Surface: x- 275,050.910 y- 2,362,053.940 Zone- TPI x- 274,162.550 y- 2,363,701.490 Zone- Total Depth x- 273,929.710 y- 2,364,084.650 Zone- 18. Directional Survey: Yes~ NoD NA feet MD 19. Water Depth, if Offshore: NA feet MSL 21. Logs Run: SP/GR-IEL-Density/Neutron-Sonic-Single Arm Caliper 1b. Well Class: Development Service Stratigraphic Test Permit to Drill Number: 203-183 API Number: 50- 133-2052900 14. Well Name and Number Kenai Beluga Unit 33-6X 15. FieIdlPool(s): Beluga & Tyonek 16. Property Designation: A-028083 17. Land Use Permit: NA 20. Thickness of Permafrost: NA 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT SIZE FT. TOP BOTTOM TOP BOTTOM PULLED 20" 133.0 K-55 0 139 0 139 Driven NA Na 13-3/8" 68.0 K-55 0 1512 0 1512 16" 320 sx NA 9-5/8" 47.0 L-80 0 5752 0 5246 12-1/4" 705 sx NA 3-1/2" 9.3 L-80 0 8362 0 7801 8-1/2" 1150 sx 78,000 23. Perforations Open to Production (MD + TVD of Top and Bottom Interval, Size, and Number; if none, state "none"): MD: 6119-6129, 6196-6206, 6279-6289, 6444-6454, 6543-6553, 6681-6691, 6724-6734,6781-6791,6858-6868,7084-7094,7122-7132, 7169-7179, 7240- 7250,7301-7311,7379-7389,7505-7515,7791-7801, 7967-7977, 8102-8112, 8197-8207 TVD: 5591-5601,5665-5675,5745-5754,5904-5914,6000-6010,6135-6145, 6177-6187,6233-6243,6309-6319,6532-6542,6570-6580, 6616-6626, 6687-6697, 6747-6757,6824-6834,6949-6959,7233-7243,7408-7418, 7542-7552, 7637-7647 24. SIZE 3-1/2" TUBING RECORD DEPTH SET (MD) 8362 PACKER SET (MD) NA 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See No. 23 28,400 to 46,000 Ibs 20140 Ottawa Sand 26. PRODUCTION TEST Date of First Production: 2/2/2004 IMethod of Operation (Flowing, Gas Lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas- MCF: 2/20/2004 24 Test Period -. NA NA Flow. Tubing Casing Pressure Calculated Oil-Bbl: Gas- MCF: Press: 1050 0 24-Hour Ratl-. NA 6174 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, if nessary). Submit core chips; if none, state "none". Flowing Water-Bbl: NA Water-Bbl: 127 None Form 10-407 Revised 4/2003 o R \ G \ N A LONTINUED ON REVERSE SIDE Choke Size: IGaS-Oil Ratio: 64164th NA oil Gravity - API (corr): NA {'--'-"-'---- ¡ GOMDI,r:T10N ì ',',' .. ,: E"'~- h I _ ~ I i !JfI! µ,p ;~ .:> iY, . , .u¡;:¡;¡r0,q , " t ~JJ '~ j ; , J..J 0..-.._..,...-.'.. -~.- b . . NAME GEOLOGIC MARKERS MD 29. FORMATION TESTS 28. TVD Include and briefly summarize test resutts. List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None". None None 30. List of Attachments: Directional Survey, Operations summary, Wellbore Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name James R. Thomspon S;gM,"œ~ ¡¿~ Title Sr. Completions Engineer Phone 907-529-0524/713-296-2730 Date 5/12/2004 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex.50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 27: If no cores taken, indicate "none. '. Item 28: List all test information. If none, state "None'. Form 10-407 Revised 4/2003 . *HEADER GEOLOG LOG Geolog Dump File *CONSTANTS HOLE = KBU 33-6X /* SET = TOPS-/* *NAMES DEPTH POINT FEET DOUBLE $Values changed using TEXT_EDIT $, INTERPOLATION=POINT $, VERSION=l $, SOURCE=TEXT_EDIT INTERVAL 1 TXT ALPHA*16 $Values changed using TEXT EDIT $, VERSION=l $, SOURCE=TEXT_EDIT $, LOGGED_DIRECTION=DOWN *DATA 3775 5098 5868 6583 7763 8405 TKS U.BELUGA M.BELUGA L.BELUGA TKT TD h or /MAti'^- . ""fp~ ;lD~-Jf) legal Well Name: Common Well Name: Event Name: . . Marathon Oil Company Final Weill Event Summary Page 1 of 2 ._---_._~.....:_~. _.._-_._._----~_._~-_._.._'"..,_._--~~~-_. KENAI BELUGA UNIT 33-6X KENAI BELUGA UNIT 33-6X ORIGINAL DRilLING TMD Start Date: 12/9/2003 24 HOUR SUMMARY End Date: DATE 12/13/2003 139 (ft) 12/14/2003 1,232 (ft) 12/15/2003 1,518 (ft) 12/16/2003 1,518 (ft) 12/17/2003 1,518 (ft) 12/18/2003 1,518 (ft) 12/19/2003 1,518 (ft) 12/20/2003 1,671 (ft) 12/21/2003 2,547 (ft) 12/22/2003 3,393 (ft) 12/23/2003 4,189 (ft) 12/24/2003 5,005 (ft) 12/25/2003 5,316 (ft) 12/26/2003 5,650 (ft) 12/27/2003 5,775 (ft) 12/2812003 5,775 (ft) Install & function test 20" diverter. Mix spud mud. P/U 4" DP & 5" HWDP. M/U clean out BHA. Tag fill @ 41' RKB. Spud well @ 05:00 hrs, 12/13/2003. C/O fill inside 20" conductor f/41' to 87'. Flow line plugging off. c/o conductor f/87' to 139' MD. CBU. P/U MWD. Drill f/139' to 1232' MD. MWD malfunction. CBU. Trip for MWD. Trip, change pulsar in MWD. Drill f/1232' to 1518' MD. CBU. WT. CBU. Trip to run 13-3/8" casing. P/U 4" DP. RIU & run 13-3/8" casing. Run & cement 13-3/8" surface casing. woe. NO diverter. Make rough cut on 13-3/8" casing. N/D diverter, remove starting head. Cut off 20" casing, make final cut on 13-3/8" casing. Install Multibowl wellhead. N/U 13-5/8" 5M dbl ram w/ annular BOP. Mix new mud. N/U BOPE. RIU choke house and beaver slide. Mix mud. Test BOPE. P/U DP. P/U 4" DP. P/U 12 1/4" BHA. RIH. Test CSG. Drill out shoe tract and shoe. Drill F/1518' to 1538'. Perform LOT to 14.2ppg EMW. Drill F/1538' to 1671'. Drill F/1617' to 2533'. Circ. clean. POOH. C/O MWD and wire up centrifudge unit. RIH. Drill F/2533' to 2547'. Circ. POOH. POOH to MWD. C/O MWD. RIH. Drill F/2547' to 3051. Rig repair. Drill F/3051, to 3393'. Drill F/3393' to 3585'. Circ. clean. POOH to CSG shoe. Service rig. RIH. Drill F/3585' to 4189'. Drill F/4189' to 4732'. Circ. clean. POOH to 3000'. Service rig. RIH. Drill F/4736' to 5005'. Drill F/5005' to 5316'. Attempt to slide. Motor stalled several times. POOH. C/O bit and motor. RIH. RIH. Drill F/5316' to 5650'. Drill F/5650' to 5775'. Circ. clean. POOH to CSG shoe. RIH. Circ. dean. POOH. POOH UD bit and dir. tools. C/O rams to 9 5/8" CSG rams. Test BOP. RIU to run CSG. Run 9 5/8" CSG. Printed: 5/1712004 2:03:06 PM . . Marathon Oil Company Final Weill Event Summary Page 2 of 2 __~._.__m___._.__·.'_ legal Well Name: Common Well Name: Event Name: DATE 12/29/2003 12/30/2003 12/31/2003 KENAI BELUGA UNIT 33-6X KENAI BELUGA UNIT 33-6X ORIGINAL DRilLING TMD 5,775 (ft) 5,775 (ft) 5,945 (ft) 1/1/2004 6,998 (ft) 1/2/2004 8,277 (ft) 1/3/2004 8,405 (ft) 1/4/2004 8,405 (ft) Start Date: 12/9/2003 24 HOUR SUMMARY End Date: Run and cement 9 5/8" CSG. Set 9 5/8" packoff assy and test. Test BOPE. Clean pits and mix mud. Test BOP. N/O BOP. N/U BOP. Test BOP. Run wear bushing. Prep to P/U BHA. RIH w/HWOP. Test CSG. Organize rig. P/U OP RIH. Tag cement. Orill shoe tract. Orill5775' to 5795'. C/O to new mud. Perform LOT. Orill5795' to 5945'. Orill f/5945' to 6523'. Hole packing off, CBU. Orill f/6523' to 6998'. CBU. Wiper trip to shoe. Orill f/6998' to 8277'. C & C mud to 10.3 ppg. Circulate & raise MW to 10.3 ppg. Orill f/8277' to 8338'. CBU. Wiper trip to 6998'. Orilled to 8405'. Circulate for logs & raise MW to 10.7 ppg. POOH for open hole logs. RlU loggers. RlU loggers. Run open hole logs. RIO loggers. Go to completion @ 13:30 hrs, 01/03/2004. Printed: 5/1712004 2:03:06 PM Legal Well Name: Common Well Name: Event Name: DATE 1/4/2004 1/5/2004 1/6/2004 1/7/2004 1/8/2004 1/9/2004 . . Marathon Oil Company Final Weill Event Summary Page 1 of 1 ---"~'.._~.-.-......_~------.~--~.--'...------- -.--'. .- --_.----~- -' -~._.,--.-._--,.__._.._.__.__.__._--------_.._'- ~---_._~------------~ KENAI BELUGA UNIT 33-6X KENAI BELUGA UNIT 33-6X ORIGINAL COMPLETION TMD 8,405 (ft) 8,405 (ft) 8,405 (ft) 8,405 (ft) 8,405 (ft) 8,405 (ft) Start Date: 12/30/2003 24 HOUR SUMMARY End Date: Change bell nipple. SR. Slip/cut drill line. TIH to shoe. CBU. Circulate & condition mud to 11.0 ppg. TIH. Wash/ream f/8270' to 8405'. Circulate & condition mud to 11.3 ppg. Pump to shoe. POOH LOOP. Finish LO OP & BHA. RIU & run 3-1/2" Excape completion. Finish run 3-1/2" Excape completion. CBU. Break circulation @ top of modules & csg shoe. Run correlation log. Put casing on depth. Circulate while batch mix cement. Cement casing. woe. N/O, lift BOP & set casing slips. Remove BOP. Install packoff. Install tree. Install & test tree. Clean rig. ROMO. Rig released @ 00:00 hrs, 1/9/2004. Printed: 5/1712004 2:03:20 PM -~-~._~_._--_._----------_._- Legal Well Name: Common Well Name: Event Name: DATE 2/1/2004 2/6/2004 2n /2004 2/8/2004 2/9/2004 . . Marathon Oil Company Final Weill Event Summary Page 1 of 1 _.~---'----.------.--~---- -_..-------_.__._------------~--------~-----~._--._--- KENAI BELUGA UNIT 33-6X KENAI BELUGA UNIT 33-6X ORIGINAL COMPLETION TMD 8,405 (ft) 8,405 (ft) 8,405 (ft) 8,405 (ft) 8,405 (ft) Start Date: 1/22/2004 24 HOUR SUMMARY End Date: Held PJSM. Fracture stimulate modules 1 through 7. Ran out of crosslink chemical. Trouble shoot crosslinking chemical delivery system. RIH with coil tubing and cleanout well. Jet well in and turn well to production for cleanup. Wait on crosslinker. Perform Escape frac treatments on Modules 8 thru 20. Rig up efT, clean out well and jet in with N2. Flow well to Clean-up through gas buster. Well Clean-up operations. Flow well to clean-up through gas buster, sand buster and Halliburton test spread. Well Clean-up operations. Flow well to clean-up. Well loaded and died. Clean out well w/ BJ CoilTech 1-3/4" efT and jet in with N2. Flow well to Clean-up through gas buster, sand buster and Halliburton test spread.. Printed: 5/17/2004 2:03:36 PM . . MARATHON Oil Company Pad 41-7 KB033-6X slot KBU33-6X Kenai Gas Field Kenai Peninsula, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-8405> svy6998 Date printed Date created Last revised 6-Jan-2004 15-Dec-2003 4-Jan-2004 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on 270916.030,2362063.980,999.00000,N Slot location is n60 27 34.652,w151 14 46.367 Slot Grid coordinates are N 2362050.001, E 275050.000 Slot local coordinates are 65.69 N 4133.64 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 0.00 239.00 335.00 414.00 510.00 605.00 701.00 797.00 893.00 1083.00 1179.00 1275.00 1370.00 1463.00 1520.00 1616.00 1712.00 1807.00 1903.00 1999.00 2094.00 2190.00 2286.00 2381.00 2477.00 10.70 11.90 13.60 15.50 17.80 2572.00 2668.00 2764.00 2860.00 2955.00 19.30 21.40 23.50 25.60 28.80 3051.00 3147.00 3242.00 3338.00 3434.00 32.40 36.10 36.50 36.20 35.80 3529.00 3625.00 3721.00 3817.00 3912.00 35.10 36.50 36.30 35.80 35.20 4008.00 4103.00 4199.00 4295.00 4390.00 34.50 34.60 36.00 35.90 35.60 4486.00 4582.00 4677.00 4773.00 4869.00 35.20 34.60 33.90 33.90 33.40 Azimuth Degrees 0.00 0.10 0.10 0.10 0.40 0.00 22.90 14.50 286.60 115.40 True Vert Depth 0.00 239.00 335.00 414.00 510.00 605.00 700.99 796.99 892.98 1082.96 1178.95 1274.94 1369.92 1462.90 1519.89 1615.85 1711.81 1806.64 1902.16 1997.24 2090.85 2184.99 2278.62 2370.58 2462.55 2552.63 2642.63 2731. 35 2818.67 2903.15 2985.77 3065.11 3141.67 3218.99 3296.66 3374.05 3451.91 3529.18 3606.80 3684.14 3762.92 3841.16 3919.51 3997.23 4074.33 4152.58 4231.31 4309.84 4389.52 4469.43 R E eTA N G U L A R COO R DIN ATE S O.OON o .19N 0.35N 0.44N 0.32N 0.56N 0.93N l.OlN l. 33N 1.74N 2.28N 3.54N 4.83N 5.98N 6.91N 8.75N 11. 4 ON 16.32N 23.81N 32.71N 42.82N 55.11N 69.99N 87.97N 109.72N 135.35N 165.30N 198.41N 234.39N 273.67N 317.76N 366.00N 415.75N 466.01N 515.97N 564.82N 614.23N 664.03N 713.42N 761.41N 808.94N 855.67N 903.73N 952.34N 1000.14N 1048.06N 1095.46N 1141. 62N 1187.80N 1233.61N O.OOE 0.08E o .13E o .09E 0.31E 0.95E 1.59E 2.46E 3.67E 6.37E 7.48E 8.36E 9.46E 11.01E 12.10E 13.92E 14.96E 12.89E 6.90E 2.78W 15.40W 29.63W 44.69W 60.36W 77 . 18W 93.03W 107.76W 123.49W 140.69W 159.20W 180.26W 204.56W 230.79W 257.46W 283.69W 309.17W 335.85W 363.51W 390.94W 418.15W 445.53W 472.35W 500.05W 528.57W 556.78W 585.01W 612.76W 639.73W 666.83W 693.87W Dogleg Deg/100ft SURVEY LISTING Your ref Last revised 0.00 0.04 0.02 0.18 0.52 0.67 0.50 0.38 0.16 0.15 0.02 0.03 -0.33 -0.65 -1.62 . Page 1 MWD <0-8405> 4-Jan-2004 Vert Sect G RID Easting COO R D S Northing 2362050.00 2362050.19 2362050.35 2362050.44 2362050.31 2362050.54 2362050.90 2362050.97 2362051.25 2362051.62 2362052.14 2362053.38 2362054.65 2362055.77 2362056.67 2362058.48 2362061.11 2362066.06 2362073.67 2362082.76 2362093.11 2362105.67 2362120.84 2362139.11 2362161.18 2362187.11 2362217.34 2362250.74 2362287.05 2362326.67 2362371.16 2362419.86 2362470.10 2362520.87 2362571.32 2362620.65 2362670.56 2362720.88 2362770.79 2362819.30 2362867.34 2362914.58 2362963.16 2363012.31 2363060.64 2363109.09 2363157.02 2363203.69 2363250.38 2363296.70 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level: Bottom hole distance is 2319.67 on azimuth 330.01 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 330.50 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.62 0.35 0.70 0.79 0.88 41.89 92 .51 80.56 71.10 90.40 0.79 1.05 1.00 1. 40 1. 50 34.50 35.20 46.10 58.80 40.70 1. 60 2.10 4.60 6.90 8.90 48.30 1.30 326.40 318.00 308.40 309.00 312.40 316.65 320.90 323.50 332.70 334.80 334.40 334.50 335.00 334.00 332.60 331.80 332.30 332.30 332.60 330.70 331.20 330.70 330.20 329.90 330.40 329.70 329.50 329.40 329.60 329.70 329.70 329.50 329.40 0.82 0.27 0.21 0.51 0.82 -1.70 -1.03 -0.45 -0.22 0.06 0.24 1. 61 3.28 2.54 2.49 0.76 2.56 7.85 17.33 29.84 1. 90 1.43 2.02 2.29 2.52 44.85 62.55 82.92 106.29 133.50 3.46 2.32 2.19 2.19 3.38 163.61 196.93 233.50 273.29 316.58 3.79 3.94 0.65 0.44 0.42 365.33 419.28 475.49 532.37 588.77 0.76 1. 86 0.37 0.60 0.70 643.84 699.98 756.94 813.44 868.60 0.75 0.32 1. 52 0.16 0.32 923.46 977.33 1032.80 1089.16 1144.65 0.43 0.63 0.74 0.12 0.52 1200.25 1255.17 1308.63 1362.17 1415.36 0.00 0.13 0.24 0.34 0.12 275050.00 275050.08 275050.14 275050.09 275050.31 275050.96 275051.61 275052.48 275053.69 275056.40 275057.52 275058.43 275059.55 275061.13 275062.23 275064.08 275065.17 275063.20 275057.36 275047.85 275035.43 275021.44 275006.67 274991.34 274974.95 274959.60 274945.45 274930.36 274913.86 274896.11 274875.91 274852.54 274827.28 274801.58 274776.32 274751.78 274726.06 274699.37 274672 .89 274646.62 274620.15 274594.24 274567.48 274539.90 274512.62 274485.32 274458.49 274432.41 274406.21 274380.06 . . MARATHON Oil Company SURVEY LISTING Page 2 Pad 41-7,KBU33-6X Your ref MWD <0-8405> Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 4-Jan-2004 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C OORDS Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg /l 00 ft Sect Easting Northing 4964.00 33.00 329.70 4548.93 1278.45N 720.23W 0.46 1467.37 274354.57 2363342.04 5060.00 32.10 329.30 4629.85 1322.96N 746.44W 0.96 1519.01 274329.22 2363387.04 5156.00 31.80 330.20 4711.30 1366.84N 772.04W 0.59 1569.81 274304.48 2363431. 41 5251. 00 31.40 330.00 4792.22 1409.99N 796.85W 0.44 1619.58 274280.50 2363475.03 5347.00 28.40 330.50 4875.43 1451.53N 820.60W 3.14 1667.43 274257.55 2363517.02 5443.00 25.60 332.20 4960.96 1489.76N 841.52W 3.03 1711.00 274237.38 2363555.64 5539.00 23.60 331.70 5048.24 1525.03N 860.31W 2.09 1750.95 274219.27 2363591.26 5634.00 21.50 331. 40 5135.97 1557.06N 877.66W 2.21 1787.37 274202.55 2363623.62 5718.00 21.30 330.30 5214.18 1583.82N 892.58W 0.53 ]818.02 274188.14 2363650.67 5795.00 21.20 330.10 5285.95 1608.04N 906.45W 0.16 1845.93 274174.74 2363675.15 5890.00 20.80 329.90 5374.64 1637.53N 923.48W 0.43 1879.97 274158.29 2363704.95 5986.00 18.40 331. 20 5465.07 1665.55N 939.33W 2.54 1912.17 274142.98 2363733.28 6082.00 18.40 331.90 5556.16 1692.20N 953.76W 0.23 1942.47 274129.06 2363760.19 6177.00 16.70 329 . 50 5646.74 1717 . 1 9N 967.75W 1. 94 1971.11 274115.56 2363785.45 6273.00 16.20 330.60 5738.81 1740.74N 981. 33W 0.61 1998.29 274102.44 2363809.25 6368.00 14.50 331. 80 5830.41 1762.77N 993.45W 1. 82 2023.43 274090.74 2363831.51 6464.00 14.30 328.70 5923.40 1783.49N 1005.29W 0.83 2047.30 274079.30 2363852.46 6560.00 12.20 327.70 6016.84 1802.19N 1016.87W 2.20 2069.28 274068.08 2363871.38 6656.00 12.00 327.50 6110.71 1819.19N 1027.66W 0.21 2089.38 274057.63 2363888.58 6751.00 10.40 324.70 6203.89 1834.51N 1037.92W 1. 78 2107.77 274047.67 2363904.10 6847.00 10.20 323.20 6298.35 1848.39N 1048.02W 0.35 2124.83 274037.84 2363918.17 6943.00 9.30 327.80 6392.96 1861.76N 1057.24W 1.24 2141.01 274028.87 2363931.72 7039.00 8.80 327.10 6487.77 1874.49N 1065.36W 0.53 2156.09 274021.00 2363944.60 7134.00 8.30 327.20 6581.71 1886.36N 1073.03W 0.53 2170.19 274013.57 2363956.61 7230.00 8.30 327.20 6676.70 1898.01N 1080.53W 0.00 2184.02 274006.28 2363968.40 7325.00 8.10 327.40 6770.73 1909.41N 1087.85W 0.21 2197.55 273999.19 2363979.94 7421. 00 7.70 326.40 6865.82 1920.46N 1095.06W 0.44 2210.72 273992.20 2363991.13 7517.00 7.20 325.30 6961. 01 1930.77N 1102.04W 0.54 2223.12 273985.41 2364001.57 7612.00 6.80 323.00 7055.30 1940.15N 1108.81W 0.51 2234.63 273978.82 2364011.08 7708.00 6.90 323.10 7150.62 1949.30N 1115.70W 0.10 2245.98 273972 .12 2364020.36 7804.00 6.60 321. 60 7245.95 1958.24N 1122.59W 0.36 2257.15 273965.40 2364029.43 7900.00 6.20 324.40 7341.35 1966.78N 1129.03W 0.53 2267.76 273959.12 2364038.09 7995.00 6.40 324.50 7435.78 1975.26N 1135.09W 0.21 2278.12 273953.23 2364046.69 8091. 00 6.20 323.00 7531.20 1983.75N 1141.32W 0.27 2288.58 273947.17 2364055.30 8187.00 5.70 326.00 7626.68 1991.85N 1147.10W 0.61 2298.48 273941. 54 2364063.50 8282.00 5.40 323.80 7721.24 1999.37N 1152.38W 0.39 2307.62 273936.41 2364071.12 8350.00 5.70 324.30 7788.92 2004.69N 1156.24W 0.45 2314.15 273932.65 2364076.52 8405.00 5.70 324.30 7843.65 2009.13N 1159.43W 0.00 2319.58 273929.55 2364081.01 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level Bottom hole distance is 2319.67 on azimuth 330.01 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 330.50 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 4l-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 2286.00 2278.62 8405.00 7843.65 Top MD Top TVD Rectangular Coords. . SURVEY LISTING Your ref Last revised : Comment Comments in wellpath -------------------- -------------------- 69.99N 2009.13N 44.69W Interpolated Survey l159.43W Projection to TO Rectangular coords. Casing positions in string 'A' ------------------------------ ------------------------------ Bot MD Bot TVD Page 3 MWD <0-8405> 4-Jan-2004 Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 13 3/8 Casing 9 5/8 Casing 3 1/2 Liner 0.00 0.00 0.00 0.00 0.00 0.00 Target name O.OON O.OON O.OON O.OOE O.OOE O.OOE 1512.00 5752.00 8405.00 1511.89 5245.86 7843.65 6.75N l594.54N 2009.13N Geographic Location Targets associated with this wellpath ------------------------------------- .- ----- -- ------ --- --- - - -- --- -- - ------- T.V.D. 11. 96E 898.71W 1159.43W 1658.49N 1916.36N Rectangular Coordinates 824.14W 23-Sep-2003 1197.20W 23-Sep-2003 ----------------------------------------------------------------------------------------------------------- Revised KBU33-6X - TIMid Bel 274258.000,2363724.000,999.00 KBU33-6X - TO - 9/22 273890.000,2363989.000,999.00 5345.40 7720.40 API: 50-133-2052900 RT-GL: 16.40' RT-THF: 16.80' 42'FSL,860'FEL,Sec.6, T4N, R11W, S.M. Tree cxn = 4-314" Otis TOC (est.) - ???' . Excape System Details - BHP monitoring line volume tank located from 6055' - 6093' Excaoe Svstem Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 1 - NA Module 2 - 8131.5' Module 3 - 7995.5' Module 4 - 7822.2' Module 5 - 7532.4' Module 6 - 7407.7' Module 7 - 7327.5' Module 8 - 7266.3' Module 9 - 7196.1' Module 10 - 7149.3' Module 11 - 7110.3' Module 12 - 6887.5' Module 13 - 6809.3' Module 14 - 6752.4' Module 15 - 6709.5' Module 16 - 6572.5' Module 17 - 6470.9' Module 18 - 6306.4' Module 19 - 6223.8' Module 20 - 6147.5' Well Name & Number: County or Parish: Perforations (MD) Angle/Perfs I BHP: Dated Completed: Prepared By: KBU 33-6X t~' (~J ~~, ..~~ ~~., .,.......Át: . 't . '<~ \~:~ k~"~~ ):)j~, "";'¡It '~~'i :,í~Y ~ ~ j.I. ~~:tí ª ~i '...., It ;; ooC t~ :ít ~ ,¡;¡ ~:Jj , ~ :-; ~.:¡ -,'-, "':_~ J.' ," '~ ~ .~ ~ :::2 .'1$. , 3 '1"t ~~ "1~ ";',e 'l<J \\1 f~ ~ ~~ ~ KBU 33-6X Kenai ~ i; TD - 8405' PBTD - 8324' ,.þ ;'~';'~'!~''-¡;' :'~,i -~~ ~1 " . t. fI'~" ïï·:;..··'w... . 'J'. . ".l~_~~ . ..~ ""'....j , ».~ ¡'--:~ .,1 ...r:. )~~~, )-~ ¡t~~ "J __ .., . :,. ~ ~ ... ~ l~ ~-~ )1, ),i ~ ~ ~~ ~ í.2 .. !i ~ ..;¡ ~ ?'': .~ :~ I ~ )J ~ ~ ~-~ ),. J~ 'it: ~ ~ ~ . (lY!) oN ~ ~ I Lease: StatelProv. I Drive Pioe: 20",133 ppf, K-55 to 139' Surface Casino: 13-3/8", 68 ppf, K-55, BTC @ 1512' Cmt wI 320 sks of class G In!. Casino: 9-5/8", 47 ppf, L-80, BTC @ 5752' Cmt w/705 sks of class G Prod. Tubino: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" 00 control line protectors to 8362' Cmt wI 1150 sks of class G Excaoe Svstem Details - 20 Excape modules placed - Green control line fires bottom 3 modules - Yellow contolline fires middle 8 modules - Red control line fires top 9 modules - Ceramic flapper valves below each module Perfs MD (RKB): Module 1 - 8197'-8207' Module 2 - 8102'-8112' Module 3 -7967'-7977' Module 4 - 7791'-7801' Module 5 - 7505'-7515' Module 6 -7379'-7389' Module 7 - 7301'-7311' Module 8 -7240'-7250' Module 9 - 7169'-7179' Module 10 - 7122'-7132' Module 11 - 7084'-7094' Module 12 - 6858'-6868' Module 13 - 6781'-6791' Module 14 - 6724'-6734' Module 15 - 6681'-6691' Module 16 - 6543'-6553' Module 17 - 6444'-6454' Module 18 - 6279'-6289' Module 19 - 6196'-6206' Module 20 - 6119'-6129' Alaska (TVD) Kenai Gas Field Country: Angle @ KOP and Depth BHT: I I Completion Fluid: 1/9/2004 J. R. Thompson I Last Revison Date: 6% KCL 1/15/2004 1!Æ~~ (illr !Æ~!Æ~~~!Æ AI4ASIiA. OIL AND GAS CONSERVATION COMMISSION S. S. Lambe Senior Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage AK 99519 . FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kenai Gas Field KED 33-6X Marathon Oil Company Permit No: 203-183 Surface Location: 65' FSL, 4133' FWL, Sec. 6, T4N, R11W, SM Bottomhole Location: 1981' FSL, 2936' FWL, Sec. 6, T4N, R11 W, SM Dear Mr. Lambe: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ ~d-~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thista day of October, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section g:lcmnldrlglsterlinglsu44-10IKBU 33-6X AOGCC Drilling 7rmil.XIS . WGÁ p~I2.7 ¿OO~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISIN PERMIT TO DRILL 210 MC 25.005 1a. Type of Work Drill[8] Re-EntryD 2. Name of Operator MARATHON OIL COMPANY Re-Drill D Deepen D 1 b. Type of well. ExploratoryD Stratigraphic TestD ServiceD Development Gas [8] Single zoneD 5. Datum Elevation (DF or KB) 10. Field and Pool 82.4' KB feet Kenai Gas Field / Beluga Development Oil D Multiple Zone [8] 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 65' FSL, 4,133' FWL, Sec. 6, T4N, R11W, S.M. At top of Productive Interval 1,712' FSL, 3,324' FWL, Sec. 6, T4N, R11W, S.M. At Total Depth 1,981' FSL, 2,936' FWL, Sec. 6, T4N, R11W, S.M. 12. Distance to Nearest 13. Distance to Nearest Well Property Line(unit boundary} 3250 feet 200 feet 16. To be Completed for Deviated Wells Kickoff Depth 1750 feet Maximum Hole Angle 43.2 0 18. Casing Program Size Specifications Hole Casing Weight Grade Coupling Driven 20" 133 X-56 PE 16" 13-3/8" 68 K-55 BTC 12-1/4" 9-5/8" 40 L-80 BTC 8-1/2" 3-1/2" 9.3 L-80 EUE 8rd 6. Property Designation A-028083 7. Unit or Property Name Kenai Beluga Unit 8. Well Number / KBU 33-6X 9. Approximate Spud Date 12/01/03 ./ 14. Number of Acres in Property 11. Type Bond (see 20 MC 25.025) Blanket Surety Number 5194234 Amount $200,000 15. Proposed Depth (MD and TVD) 2345 8,320' MD /7,725' TVD feet 17. Anticipated Pressure (see;W MC 25.035 (e) (2» Maximum Surface 3433 /PSi9 at Total Depth (TVD) 7725' Setting Depth Top Bottom Quantity of Cement (including stage data) Length MD TVD MD TVD "+/-120 0' 0' 120 120 1500' 0' 0' 1500' 1500' 5800' 0' 0' 5800' 5250' 8320' 0' 0' 8320' 7725' 378 sx ,/ 640 sx ./ 1220 sx / The KBU 33-6X well will be directionally drilled to an estimated total depth of 8320' MD, 7725' TVD from the existing Kenai Gas Field pad 41-7. The production interval will be cased with 3-1/2" casing, cemented in place, and run to / surface. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Pad drawing, Location Map, Structure Map, Surface use plan, Directional Maps, Mud Pit and Blowout Preventer drawings. 20. Attachments Filing Fee[8] Property Plat[8] BOP Sketch [8] Drilling Fluid Program 0 Time vs Depth PlotD Refraction AnalYSiSD 21. I hereby certify that the foregoing is true and correct to e best of my knowledge Phone: 907-564-6332 . i1--/ Signed S. S. Lambe M / - t Title Senior Drilling Engineer Commission Use Only IAPI Number I Approval D.alJ. 50-- /.31-.2.ò ~:2. 9 !Q/l.8/oJ Conditions of Approval Samples Required DYes ~NO Mud Log Required DYes ~NO Hydrogen Sulfide Measures DYes 1:81 No Directional Survey Required lZIYes DNO Required Working Pressure for BOPE D2M D3M D5M D10M D15M Other: T~$t- ßOPE +-.0 ~SDO rs.(" Diverter Sketch [8] Seabed ReportD Drilling Program [8] 20 AAC 25.050 RequirementsD Permit Number .203 - /'l 3 Approved by ~ tf!?- ./.- Form 10-401 Rev. 12-1-85 _\~ Date 10/24/2003 s.e..e. cove.r. Letter . For Other Requirements ,. ". " 4 Commissioner URIGif\~AL by order of the Commission Date /~~&Jcate It . MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM Kenai Gas Field KBU 33-6X Revised 10/17/03 )/. Originator: 8.8. Lambe . Drilling Superintendent: P.K. Berqa Drilling Manager: C.W. Truby Page 1 of 13 e e Table of Contents General Well Data...................................................................................................................................... .............................3 Geologic Program Summary.................................................................................................................................. .................3 Summary of Potential Drilling Hazards.................................................................................................................. ....... ...........4 Formation Evaluation Summary ............................................................................................................................. .................4 Drill ing Program Summary........................................................................................................................ ...............................5 Casing Program....................................................................................................................... ................................................6 Casing Design .............................................................................................................................. ...........................................6 Maximum Anticipated Surface Pressure .................................................................................................................................6 BOPE Program..................................................................................................................................... .............. .....................7 Wellhead Equipment Summary.. .... .................... .................. ............................................ ....................... .......................... .....8 Directional Program Summary.............................................................................................................................. ..................8 Directional Surveying Summary ...... ........................................... .......... ......................... ..................... ....... ................ ......... ... ..9 Drilling Fluid Program Summary................................................................ ................... ........................................... ... .............9 Drilling Fluid Specifications.... ........................... ... .... ................... .................................... .......... ............. .............. ... ........ ...... ...9 Solids Control Equipment.................................................... ...................... ......................................................... ................. ..10 Cement Program Summary....................................................................................................................................... ........... .11 Regulatory Waivers and Special Procedures.... ......................................................................................................... .......... .11 Bit Summary ............................................................................................................................................... ............... ........... .12 Hydraulics Summary.................................................................................................................................... ......................... .12 Formation Integrity Test Procedure.................................................................................................................................. ... ..13 Page 2 of 13 General Well Data Well Name Surface Location Slot/Pad KB Elev. Ground Level Elev. Perm. Datum Water Depth Water Protection Depth Comments: e e KBU 33-6X 65' FSL, 4,133' FWL, Sec. 6, T4N, R11W, S.M. Lease/License WBS Code Spud Date API No. Well Class DD.03.09501.CAPDRL 12/01/03 Pad 41-7 Field Kenai Gas Field 82.4 CountylProvince Kenai Borough 66 State I Country Alaska KB Total MD 8,315' N/A TotafTVD 7,720' Development Nabor's Rig Contractor Rig Name #129 ./ Geoloaic Proaram Summary MD - RKB TVD ~ RKB Pore Pressure Pore pressu/ Possible FlUid Formation (ft) (ft) (psi) (ppg) Lithology Content Top Sterling 3,727 3,500 1.2-7.5 Sandstone Gas I Water Beluga 5,257 4,732 Sandstone Gas I Water Top Middle Beluga 5,898 5,345 3.5 - 8.5 Sandstone Gas I Water Tyonek 72-8/73-1 7,823 7,237 3.5 - 8.5 Sandstone Gas I Water Tyonek 73-1 Mid 7,987 7,397 3.5 - 8.5 Sandstone Gas I Water Tyonek 75-8 8,172 7,580 3.5 - 8.5 Sandstone Gas I Water TD 8,320 7,725 3.5 - 8.5 Sandstone Gas I Water Comments: From LeaselBlock Lines Latitude Longitude ¡(}Sf-' e "i .I.R'M North (Y) A- S fJ 2; 'i u.:fII7I'1:ast (x) Tolerance Target Beluga WellTD Surface Location Coordinates 65' FSL, 4,133' FWL, Sec. 6, T4N, R11W, S.M. 600 27' 34.652" N "'" 1510 14' 46.367" W .... 2,362,050.00' .01 275,050.00' 0/ Depth Horizontal Displacement (ft) N/S EIW (Y) (X) (ft) Circle 200' radius Circle 200' radius MD TVD (ft) (ft) Location 5,257 4,732 1,712' FSL, 3,324' FWL, Sec. 6, T4N, R11W, S.M. 1,647 -809 8,320 / 7,725 1,981' FSL, 2,936' FWL, Sec. 6, T4N, R11W, S.M. -1,197 -1,916 Page 3 of 13 e e Comments: Summary of Potential Drillina Hazards Hazard Event Discussion Lost Circulation in Low Pressure Sterling and Upper Control losses by using sufficiently sized LCM and appropriate mud weights. Beluga Sands Comments: Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. /' Gas sands will be encountered from +/- 3,726' MD (3,500' TVD) to total depth of the well. These sands will run from normal pressured to severely depleted and lost circulation and differential sticking are potential hazards. The Flo-Pro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. No well interference hazards exist. Formation Evaluation Summary Interval LWD Surface None 0' - 1,500' MD Intermediate None 1,500' - 5,800' MD Production None 5,800' - 8,320' MD Completion N/A Electric Logs Mud Logs None None None Mudlog Gas Monitor Quad Combo- Reeve's N/A Basic with GCA, shale density, temperature in and out, sample collection (10' samples). N/A Coring Requirements: None Comments: Page 4 of 13 e e Drillina Proaram Summary CONDUCTOR: 1. Drive 20" conductor to +1-120 ft. RKB. 2. Move in and rig up rotary drilling rig. 3. Install starting head 20" SOW x 21 1/4", 2M flanged. / 4. Nipple up 21 1/4", 2M diverter, 16" divertervalve, and 16" diverter line. 5. Function test diverter and diverter valve. SURFACE: 1. 2. Drill a 16" hole to 1,500' MD (1,500' TVD) per the directional plan. RI H with 13 3/8" casing and hang off in the slips. Make up stab-in sub and centralizer on 4" drill pipe. TI H with inner string and latch into stab-in float collar. Cement 13 3/8" casing. Sting out and circulate drill pipe clean. TOOH with inner string. PU 13 3/8" casing, set casing slips in 20", cut off 13 3/8", ND diverter. Install 13 318" slip lock connection X 13 5/8" 5M flanged multibowl wellhead. NU 135/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3,500 psi. Set wear bushing. Test surface casing to 1,000 psi. /' 3. 4. 5. 6. 7. INTERMEDIATE: 1. Drill out float equipment and make 20' of new hole. CBU. 2. Test shoe to leak off. --Ëstimated EMW is 13 ppg. 3. Drill 12 1/4" directional hole to 5,800' MD (5,250' TVD) as per directional plan. 4. Make wiper trip. 5. Change out variable pipe rams with 9 5/8" casing rams. Run test plug and test casing rams to 3,500 psi. / 6. Run and cement 9518" casing. Land hanger in multibowl wellhead. 7. Back out landing joint. Change out 95/8" casing rams with variable pipe rams. Run test plug and test pipe rams to 250/3,500 psi. 8. Set wear bushing. Test casing to 3,500 psi. PRODUCTION: 1. 2. 3. 4. 5. 6. Drill float equipment and 20' of new formation w/8 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 13.5 ppg. / Drill a 81/2" hole to 8,320' MD (7,725' TVD) per the directional program. ./ TOOH. RU logging company. Run open hole logs as per plan. RD logging company. TIH to TD for wiper trip. TOOH and laydown BHA and drill pipe. Pull wear bushing. Run 31/2" EXCAPE casing string. RU logging company to correlate EXCAPE modules to open hole logs. RD logging company. Cement 3 1/2" casing while reciprocating. Bump plug with 500 psi over displacement pressure. WOC. / PU 3 1/2" casing. PU BOP stack. Run control and electric lines out tubing head outlet. Set slips. Cut 31/2" casing. LD BOP. Set 31/2" packoff. NU 135/8" 5M X 31/8" 5M tubing head adapter and 31/8" 5M tree. Test tree to 5,000 psi. Rig down and move out drilling rig. 7. 8. 9. 10. Note: Perforating guns will be run on the outside of the 3 1/2" production casing with a flapper valve just below each perforating gun. Guns to be activated by control line to surface. COMPLETION: Completion will be done without a rig. / Page 5 of 13 e Casin~ Pro~ram MD (ft) Casing Size (in) 13 3/8 95/8 31/2 Weig~t (Ibs/ft) 68 40 9.3 Grade K-55 L-80 L-80 Top Surface Surface Surface Bottom 1,500 5,800 8,320 Comments: e Connection API Ratings / /0.0. (in) 14.375 10.625 4.5 Makeup Torque (ft-Ibs) N/A * N/A * 3,200 Q) ¡Ii:=- co en = c. o~ Ü c 000 '00 c. áig I- ~~ Hole Size Æ .9: (in) j,1..ee-I tP 3,450 12.25 ~K5,750 8.5 10,160 Type BTC BTC 8rd 1,950 3,090 10,530 1,300 979 207 * The make up of the buttress connection will be to the proper mark. Casin~ Desi~n Casing Shoe Safety Factors / Q)/ c/ Casing Setting Mud Wt Frac. Form Maximum Surface en c. 0 Size Weight Depth When Set Grad Pressure '§ E1 '00 Press Õ c :) Q) (in) (Iblft) Grade (TVD) (Ib/gal) (Ib/gal) (Ib/gal) (pSi) C£I Ü I- 13 3/8 68 K-55 1,500 9.2 13.0 8.5 942 2.21 2.11 4.52 95/8 40 L-80 5,250 9.6 13.5 3.8 3,433 1.84 1.05 3.30 31/2 9.3 L-80 7,725 10.0 15.0 8.5 2,641 1.14 2.20 1.60 Comments: Maximum Anticipated Surface Pressure Settil'lg Depth Cåsing Size TVD MAWP * ~ ® ~~} 13 3/8 1 ,462 942 95/8 5,347 3,433 / 3 Y> 7,325 2,641 * MAWP = Maximum anticipated wellhead pressure ** MASP = Maximum anticipated surface pressure Comments: MASP CALCULATIONS: Surface casing: 13318" (1,500' MD, 1,500' TVD) MASP ** Mud/Gas (psi) Ratio 942 0/100 3,433 0/100 2,641 0/100 MASP = Injection pressure at shoe + SF - Hydrostatic pressure of gas column. MASP = (13.0 ppg + 1.0 ppg) x .052 x 1,500' - (.10 x 1,500') MASP = 1,092 psi - 150 psi MASP = 942 psi. Page 6 of 13 e Intermediate casing: 95/8" (5,800' MD, 5,250' TVD) MASP = Injection pressure at shoe + SF - Hydrostatic pressure of gas column MASP = (13.5 ppg + 1.0 ppg) x .052 x 5,250' - (.10 x 5,250') MASP = 3,958 psi - 525 psi MASP = 3,433 psi ./ Production casing: 3 1/2" (8,320' MD, 7,725' TVO) MASP = Formation pressure - Hydrostatic pressure of gas column. MASP = 8.5 ppg x .052 x 7,725' - (.10 x 7,725') MASP = 3,414 psi - 773 psi MASP = 2,641 psi. BOPE Program Casing Casing Size (in) Casing Test Test Fluid Press Density (psi) (Ib/gal) MAWP (psi) MASP (psi) Surface 133/8 918 918 1,000 9.2 Intermediate 95/8 3,497 3,500 9.6 3,497 Production 31/2 2,505 3,000 10.0 2,505 Comments: Blowout Preventers e BOPS /' Size & Rating (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets Test Pressure Low/High (psi) 250/3,500 /' 250/3,500 / 250/3,500 / The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer / with blind rams in the bottom and pipe rams in the top and a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-118" x 5000 psi outlets. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Page 7 of 13 e e Casing Test Pressures Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Wellhead Equipment Summary Component Description 13-5/8" 3M X 13-3/8" Slip Loc WI 2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL 1, PR1 13-5/8" 3M Studded Bottom X 13-5/8" 5M Fig Top, WI 2, 2-1116" 5M Studded Outlets, U,AA,PSL 1 ,PR1 13-5/8" 5M X 3-118" 5M WI Seal Pocket and 3" H BPV Threads Casing Hal'lger Typè 13 5/8" x 9 5/8" Fluted Mandrel '135/8" x 31/2" Manual Slip Casing Head Tubing Head Adapter Flange Comments: Control lines and electric cable for the EXCAPE system will be routed through the tubing head side outlet. Directional Proaram Summary Build Tum Coordinates Sec. MD TVD Rate Rate Dogleg Inclination Azimuth NIS EIW VS No. Description (ft) (ft) ("/100') (0/100') ("/100') (deg) (deg) (ft) (ft) (ft) Tie On 0 0 0 0 0 0 0 0 0 0 KOP 1750 1750 0 0 0 0 336 0 0 0 3 Build up Section 2.5 0 2.5 / 336 4 End of Build 3479 3320 2.5 0 2.5 43.23 336 569 -250 62.1 5 End of Hold 4180 3830 0 0 0 43.23 336 1009 -443 1101 6 End of DroplTurn 5898 5345 -1.89 -1.8 2.0 10.81 305 1658 -824 1852 7 TO 8,8320 7,725 0 0 0 10.81 305 1916 -1197 2249 8 10 11 Comments: Vertical section calculated from a reference azimuth of 185.910 taken from surface location to bottom hole location. Potential Well Interference: Well KBU 43-6 KBU 43-6x KTU 24-6H KTU 42-7 Distance (ft) 84.8 61.7 79.8 82.3 Depth (MD) 1300 / 2200 800 200 No serious interference exists. See attached directional plan and anticollision analysis for more details. Page 8 of 13 Directional Survevina Summary Interval MWD Survey X X X o - 1,500' 1,500' - 5,800' 5,800' - 8,320' Comments: Drillina Fluid Proaram Summary Interval.. TVD From To (ft) (ft) Density (Ib/gal) o 1 ,500 8.6 - 9.2 1,500 5,250 9.2 - 9.6 5,250 7,725 9.2-69 Comments: e Mªgnetic Multishot Fluid Description Gell Gelex Spud Mud 6% FIe-Pro wI Safecarb 6% Flo-Pro wI Safecarb e Gyro Mµltishot Additives Gel, Gelex, Soda Ash, Caustic, Barite, Polypac UL, M-I Seal, Sodium Bicarbonate Flo-Vis, KCI, Bioban BP-Plus, SafeCarb F, KlaGard, Barite, Caustic, Conqor 404, SafeScav NA, Lubetex FIe-Vis, DualFlo, KCI, Greencide 25G, SafeCarb F,M,C, Ventrol 401, Barite, Caustic, Conqor 404, SafeScav NA Comments Minimum Inventory Gel Viscosifier Barite See mud prognosis for details. Sized CaC03 (SafeCarb) will be used to controlleakoff into the low pressure zones. Drillina Fluid Specifications Interval.....TVD LSRV From To Density Vis 1 min PV (ft) (ft) (Ib/gal) (sedqt) (lb.l100tf) (cP) 0 1,500 8.6 - 9.2 45 - 75 10 - 15 1,500 5,250 92ði 40,000 8 - 14 5,250 7,725 9.2- O. 40,000 8 - 14 Comments: Page 9 of 13 YP (lb/100 tf) 20 - 40 Fluid Loss (cc) 8-12 pH MBT (Ib/bbl) <6 As recorded < 9.5 < 7.5 9.0 - 9.5 e e Solids Control Equipment c: 0 () a; (¡) tš ~ 1t' () (\) c: () 0 E .t:. à3 (II 0> U "0 Æ () .z en en en a; Ü 0> 0> Õ c: -¡:: c: c: .:£ (II ë¡¡ "0 ë E E 0 (\) en (jj .t:. () () ::J () ::J ::J Interval en 0 0 ~ ü ü Ü N Comrnents o - 8,320' MD X X X Closed Loop System, Full Containment Item Shaker Desallder Desilter Mud Cleaner Derrick Model 200 flowline cleaners Equipment Specifications (quantity, design type,brand,rnodel, flow capacity,ètc) 2 - Derrick Model 2000 Linear Motion Shakers N/A Centrifuge 2 - MllSwaco units Cuttings Dryer N/A Cuttings Injection Marathon G&I Facility Zero Discharge N/A Comments: The solids control equipment will consist of two flowline cleaners, and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. Page 10 of 13 e e Cement Proaram Summary Depth Gauge Top of Cement Open Casing Hole Ann Vol Slurry WOC Hole Size MD TVD Size MD TVD To TOC Vol Time Excess (in) (ft) (ft) (in) (ft) (ft) (ft3) (ft3) (hrs) (%) 13 3/8 1,500 1,500 16 0 0 630 945 8 50 95/8 5,800 5,250 12.25 3,000 2,939 880 1,175 16 35 31/2 8,320 7,725 8.5 5,600 5,056 960 1,440 N/A 50 Mix Water Compressive Casing Slurry TOC Strength Size Density Qty Yield Vol MD Qty WL FW (psi) (in) Slurry Cement Description (Ib/gal) (sx) (ft3/sx) (ft3) (ft) (gal/sx) Type (cc) (%) 8 hr 24 hr Lead 133/8 Tail Type I Cement 12 378/ 2.50 945 0 10.84 Fresh 812 0 500 1,183 Lead 95/8 640/ Tail Class "G" 13.5 1.84 1,175 3,000 9.28 Fresh 10 0 60 820 Lead 3 1/2 1220 /1.18 Tail Class "G" 15.7 1 ,440 5,600 5.03 Fresh 18 0 500+ 2,431 Comments: See cement prognosis for details and spacer specifications. Reaulatorv Waivers and Special Procedures I AOGCC Regulation 20 ACC 25.035 (e) (1) (b) I Requirement for 2 pipe rams, one blind ram, and one annular for a API 5K or above BOP stack. Marathon is requesting a waiver from the above regulation for KBU 33-6X. We are requesting that the BOP stack be ".,..- configured with one pipe ram instead of two, due to rig height restrictions in the running of the 3 1/2" production casing. The height restriction involves having rig crew members routing control line and electrical line through one of the tubing head outlets after the 3 1/2" casing is cemented and the BOP stack is picked up. This is prior to setting the casing on slips and cutting the casing sticking up. These lines control firing of the perforating guns and the monitoring of downhole pressure and temperature in our EXCAPE completion system. A similar waiver was requested for an offset well on this pad KBU 44-6 on 2/11/2002 and was granted. No problems were / encountered while doing this operation on the above well last year. Nø wolvvw ~~t( y ~. D.€. ~tö z;Fw- y~:r;tA.,\ :: ~S"DD r ~ Page 11 of 13 e e Bit Summary Interval - MD From To (ft) (ft) o 1,500 1,500 5,800 5,800 8,320 Type Size (in) Manufacturer Model No. 16 Christensen MX-C1 12 1/4 Christensen MX-C1 81/2 Christensen HCM605 Recommended Estimated Rotating Hours ROP (ftlhr) IADC 117 117 M323 WOS (kips) RPM 15 - 40 80 - 200 20 - 50 Motor 41 Motor Comments: Hvdraulics Summary Rig mud pumps available are shown below. Max Press @ Displacement @ Liner ID Stroke 90% WP 95% eft Max Rate Hole Sections Used Qty Make Model (in) (in) (psi) (gal/stroke) (spm/gpm) On 5 9 3,600 2.29 215/490 Surface Gardner 2 PZ9-Triplex 5 9 3,600 2.29 215/490 Intermediate Denver 5 9 3,600 2.29 215/490 Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Hole Standpipe Min Nozzle Depth-MD Size PumpRate Pressure AV ECD Size (ft) (in) (gpm) (psi) (fpm) (Ib/gal) (32"s) Remarks 1& ~* 1 -12 o - 1,500 )~ 575 1,800 46 2 - 16's Actual Data from BC #11 1 -14 1,500 - 6,471 12.25 547 3 - 22's Actual Data from BC #11 2,000 89 1 -15 6,471 - 8,485 8.5 436 1,900 148 3 - 20's Actual Data from BC #11 Comments: See separate hydraulics calculations. Page 12 of 13 e e Formation Inte~ritv Test Procedure / Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Page 13 of 13 400 - 800 - 1200 - 1600 - 2000 - 2400 - ,......., ....... 2800 - Q) Q) '+- "--"' 3200 - ..c ....... 0... Q) 0 3600 - 0 () 4000 - ....... !..... Q) > 4400 - Q) :J !..... f- 4800 - I V 5200 - 5600 - 6000 - 6400 - 6800 - 7200 - 7600 - 8000 e e MARATHON Oil Company Structure : Pod 41-7 Field : Kenai Gos Field o - ! RKB Elevation: 82A' 3 1 /2 Liner/TO TO Tgt Ll 13 3/8 Casing KOP 2.50 5.00 7.50 OLS: 2.50 deg per 100 It 10.00 12.50 15.00 17.50 20.00 2250 25.00 27.50 30.00 32.50 35.00 40.00 43.04 End of Build TANGENT ANGLE 43.23 DEG 9 5/8 Casing 43.04 42.83 End of Hold 38.90 34.97 / 33.01 31.06 29.11 27.18 25.25 23.33 21.43 19.55 17.69 15.86 14.09 12.38 ---- 9 5/8 Casing T /Mid Beluga End of Turn/Drop End 01 Hold TOl"get KBU3.3-6X - II'" 5897.55 ----- Point Tie on KOP End of Build TARGET ANGLE 10.81 DEG Well: KBU33-6X Location: Kenai Peninsula. Alaska MARATHON <- West (feet) 1200 1D00 800 400 200 600 I~I T/Mîd Beluga ./ WELL PROFILE DATA ---- .., V. Sect Deq/OO D< NO North 0.00 0.00 0.00 0.00 0.00 .336.27 1760.00 0.00 Eo,I 0.00 0.00 0.00 0.00 1750.00 0.00 0.00 0.00 3479.23 43.23 336.27 3319.76 569.41 -250.30 621.31 3.315.27 .3830.26 IOOS.75 -443.4.2 1100.68 10,51 30<.60 5J45,.w 1!5ðð.49 -624.1'1 1851.96 10,81 304,65 7720.40 1916,36 -1197.20 2248.92 0.00 2.50 0.00 2,00 rD. tl TOnjet KBU33-6X 6315.46 3 1/2 Liner/TO o 400 800 1200 1600 2000 2400 Vertical Section (feet) - > Azimuth 333.58 with reference 0.00 N, 0.00 E from slof KBU33-6X Creoted by bmtchoel Dote plotted: 3-0ct-2003 Pial Reference is KBU33-6X Version 2. o - 2000 - 1800 - 1600 - HOD ^ - 1200 I Z 0 , - 1000 -+ ::J ,......., -h - 800 CD CD -+ "--"' 600 - 400 - 200 0 FOR: S LAMBE Coordinates ore in feet reference slot KBU33-6X. rrU~ Vertical Depths ore ref~rence RKB (Nabors 129). BiB BAKIR INGHIS INTEQ - e MARATHON Oil Company Pad 41-7 KBU33-6X slot KBU33-6X Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KBU33-6X Version 2 prop5527 Date printed Date created Last revised 3-0ct-2003 23-Sep-2003 3-0ct-2003 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on 270916.030,2362063.980,999.00000,N Slot location is n60 27 34.652,w151 14 46.367 Slot Grid coordinates are N 2362050.001, E 275050.000 Slot local coordinates are 65.69 N 4133.64 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1750.00 1850.00 1950.00 2050.00 2150.00 2250.00 2350.00 5.00 7.50 10.00 12.50 15.00 2450.00 2550.00 2650.00 2750.00 2850.00 17.50 20.00 22.50 25.00 27.50 2950.00 3050.00 3150.00 3250.00 3350.00 30.00 32.50 35.00 37.50 40.00 3450.00 3479.23 3500.00 4000.00 4179.88 42.50 43.23 43.23 43.23 43.23 4200.00 4300.00 4400.00 4500.00 4600.00 42.83 40.86 38.90 36.93 34.97 4700.00 4800.00 4900.00 5000.00 5100.00 33.01 31.06 29.11 27.18 25.25 0.00 0.00 0.00 0.00 0.00 0.00 336.27 336.27 336.27 336.27 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1750.00 1849.97 1949.75 2049.14 2147.97 2246.04 2343.17 2439.17 2533.85 2627.05 2718.57 2808.25 2895.92 2981. 40 3064.54 3145.18 3223.16 3298.34 3319.76 3334.90 3699.20 3830.26 3844.96 3919.45 3996 .19 4075.08 4156.03 4238.94 4323.71 4410.23 4498.40 4588.11 RECTANGULAR COO R DIN ATE S 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 2.00 N 7.98 N 17.95 N 31. 87 N 49.73 N 71.49 N 97.11 N 126.53 N 159.71 N 196 . 57 N 237.06 N 281. 09 N 328.58 N 379.43 N 433.56 N 490.86 N 551.21 N 569.41 N 582.44 N 895.96 N 1008.75 N 1021.31 N 1082.21 N 1140.48 N 1196.05 N 1248.85 N 1298.81 N 1345.88 N 1389.99 N 1431.10 N 1469.15 N 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.88 W 3.51 W 7.89 W 14.01 W 21. 86 W 31. 43 W 42.68 W 55.62 W 70.20 W 86.41 W 104.20 W 123.56 W 144.43 W 166.79 W 190.58 W 215.77 W 242.30W 250.30 W 256.02 W 393.84 W 443.42 W 448.95 W 476.19 W 502.93 W 529.15 W 554.81 W 579.88 W 604.34 W 628.14 W 651.27 W 673.69 W Dogleg Deg/100ft e PROPOSAL LISTING Page 1 Your ref KBU33-6X Version 2 Last revised 3-0ct-2003 Vert Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 336.27 336.27 336.27 336.27 336.27 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 336.27 336.27 336.27 336.27 336.27 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.50 336.27 336.27 336.27 336.27 336.27 0.00 0.00 0.00 0.00 2.50 0.00 13 3/8 Casing 0.00 0.00 0.00 KOP 2.18 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.17 335.63 335.05 334.42 333.72 332.96 332.11 331.16 330.09 328.86 2.50 2.50 2.50 2.50 2.50 8.71 19.59 34.78 54.27 78.01 2.50 2.50 2.50 2.50 2.50 105.96 138.06 174.26 214.49 258.67 2.50 2.50 2.50 2.50 2.50 306.71 358.52 414.01 473.08 535.59 2.50 2.50 0.00 0.00 0.00 601.45 621.31 EOB 635.52 977.61 1100.68 End of Hold 2.00 2.00 2.00 2.00 2.00 1114.40 1181.06 1245.14 1306.57 1365.27 2.00 2.00 2.00 2.00 2.00 1421.17 1474.20 1524.30 1571.41 1615.46 All data is in feet unless otherwise stated. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level Bottom hole distance is 2259.59 on azimuth 328.01 degrees from wellhead. Total Dogleg for wellpath is 77.64 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company PROPOSAL LISTING Page 2 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised 3-0ct-2003 Measured Inclin. Azimuth True Vert R E C T AN G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 5200.00 23.33 327.45 4679.26 1504.10 N 695.37 W 2.00 1656.41 5300.00 21. 43 325.80 4771. 72 1535.91 N 716.30 W 2.00 1694.20 5400.00 19.55 323.84 4865.39 1564.52 N 736.44 W 2.00 1728.79 5500.00 17.69 321.50 4960.16 1589.92 N 755.77 W 2.00 1760.14 5600.00 15.86 318.62 5055.90 1612.07 N 774.26 W 2.00 1788.20 5700.00 14.09 315.03 5152.50 1630.94 N 791.90 W 2.00 1812.95 5800.00 12.38 310.45 5249.85 1646.51 N 808.66 W 2.00 1834.35 5800.16 12.38 310.44 5250.00 1646.53 N 808.69 W 2.00 1834.38 9 5/8 Casing 5897.55 10.81 304.65 5345.40 1658.49 N 824.14 W 2.00 1851.98 KBU33-6X - T/Mid Beluga - 9/22/03 5900.00 10.81 304.65 5347.81 1658.75 N 824.52 W 0.00 1852.38 6000.00 10.81 304.65 5446.04 1669.42 N 839.95 W 0.00 1868.79 6100.00 10.81 304.65 5544.26 1680.08 N 855.38 W 0.00 1885.21 6200.00 10.81 304.65 5642.49 1690.75 N 870.81 W 0.00 1901.63 6300.00 10.81 304.65 5740.71 1701. 41 N 886.24 W 0.00 1918.04 6400.00 10.81 304.65 5838.94 1712.08 N 901.67 W 0.00 1934.46 6500.00 10.81 304.65 5937.16 1722.74 N 917.09 W 0.00 1950.88 6600.00 10.81 304.65 6035.39 1733.41 N 932.52 W 0.00 1967.29 6700.00 10.81 304.65 6133.61 1744.07 N 947.95 W 0.00 1983.71 6800.00 10.81 304.65 6231. 84 1754.74 N 963.38 W 0.00 2000.12 6900.00 10.81 304.65 6330.07 1765.40 N 978.81 W 0.00 2016.54 7000.00 10.81 304.65 6428.29 1776.07 N 994.24 W 0.00 2032.96 7100.00 10.81 304.65 6526.52 1786.73 N 1009.67 W 0.00 2049.37 7200.00 10.81 304.65 6624.74 1797.40 N 1025.09 W 0.00 2065.79 7300.00 10.81 304.65 6722.97 1808.06 N 1040.52 W 0.00 2082.21 7400.00 10.81 304.65 6821.19 1818.73 N 1055.95 W 0.00 2098.62 7500.00 10.81 304.65 6919.42 1829.39 N 1071.38 W 0.00 2115.04 7600.00 10.81 304.65 7017.64 1840.06 N 1086.81 W 0.00 2131.46 7700.00 10.81 304.65 7115.87 1850.72 N 1102.24 W 0.00 2147.88 7800.00 10.81 304.65 7214.09 1861.39 N 1117.67 W 0.00 2164.29 7900.00 10.81 304.65 7312.32 1872.05 N 1133.10 W 0.00 2180.71 8000.00 10.81 304.65 7410.54 1882.72 N 1148.53 W 0.00 2197.13 8100.00 10.81 304.65 7508.77 1893.38 N 1163.95 W 0.00 2213 .54 8200.00 10.81 304.65 7606.99 1904.05 N 1179.38 W 0.00 2229.96 8300.00 10.81 304.65 7705.22 1914.71 N 1194.81 W 0.00 2246.38 8315.46 10.81 304.65 7720.40 1916.36 N 1197.20 W 0.00 2248.92 KBU33-6X - TD - 9/22/03 All data is in feet unless otherwise stated. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Bottom hole distance is 2259.59 on azimuth 328.01 degrees from wellhead. Total Dogleg for wellpath is 77.64 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field/Kenai Peninsula, Alaska Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- e PROPOSAL LISTING Page 3 Your ref KBU33-6X Version 2 Last revised: 3-0ct-2003 1500.00 1500.00 0.00 N 0.00 E 13 3/8 Casing 1750.00 1750.00 0.00 N 0.00 E KOP 3479.23 3319.76 569.41 N 250.30 W EOB 4179.88 3830.26 1008.75 N 443.42 W End of Hold 5800.16 5250.00 1646.53 N 808.69 W 9 5/8 Casing 5897.55 5345.40 1658.49 N 824.14 W KBU33-6X - T/Mid Beluga - 9/22/03 8315.46 7720.40 1916.36 N 1197.20 W KBU33-6X - TD - 9/22/03 Top MD Top TVD Bot MD Bot TVD Casing positions in string 'A' Casing ------------------------------ ------------------------------ Rectangular Coords. Rectangular Coords. ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE O.OOE O.OOE 1500.00 5800.16 n/a 1500.00 5250.00 7720.40 O.OON 1646.53N 1916.36N 13 3/8 Casing 9 5/8 Casing 3 1/2 Liner O.OOE 808.69W 1197.20W Target name T.V.D. Targets associated with this wellpath Revised ------------------------------------- ------------------------------------- Geographic Location ----------------------------------------------------- Rectangular Coordinates ------------------------------------------------------ KBU33-6X - T/Mid Bel 274258.000,2363724.000,999.00 5345.40 KBU33-6X - TD - 9/22 273890.000,2363989.000,999.00 7720.40 1658.49N 1916.36N 824.14W 23-Sep-2003 1197.20W 23-Sep-2003 · e MARATHON Oil Company Pad 41-7 KBU33-6X slot KBU33-6X Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KBU33-6X Version 2 prop5527 Date printed Date created Last revised 3-0ct-2003 23-Sep-2003 3-0ct-2003 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on 270916.030,2362063.980,999.00000,N Slot location is n60 27 34.652,w151 14 46.367 Slot Grid coordinates are N 2362050.001, E 275050.000 Slot local coordinates are 65.69 N 4133.64 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North - MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1750.00 1850.00 1950.00 2050.00 2150.00 2250.00 2350.00 5.00 7.50 10.00 12.50 15.00 2450.00 2550.00 2650.00 2750.00 2850.00 17.50 20.00 22.50 25.00 27.50 2950.00 3050.00 3150.00 3250.00 3350.00 30.00 32.50 35.00 37.50 40.00 3450.00 3479.23 3500.00 4000.00 4179.88 42.50 43.23 43.23 43.23 43.23 4200.00 4300.00 4400.00 4500.00 4600.00 42.83 40.86 38.90 36.93 34.97 4700.00 4800.00 4900.00 5000.00 5100.00 33.01 31. 06 29.11 27.18 25.25 Azimuth Degrees 0.00 0.00 0.00 336.27 True Vert Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1750.00 1849.97 1949.75 2049.14 2147.97 2246.04 2343.17 2439.17 2533.85 2627.05 2718.57 2808.25 2895.92 2981. 40 3064.54 3145.18 3223.16 3298.34 3319.76 3334.90 3699.20 3830.26 3844.96 3919.45 3996.19 4075.08 4156.03 4238.94 4323.71 4410.23 4498.40 4588.11 O.OON O.OON R E C TAN G U L A R COO R DIN ATE S O.OOE O.OOE O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON 2.00N 7.98N 17.95N 31.87N 49.73N 71 . 49N 97.11N 126.53N 159.71N 196.57N 237.06N 281.09N 328.58N 379.43N 433.56N 490.86N 551. 21N 569.41N 582.44N 895.96N 1008.75N 1021. 31N 1082.21N 1140.48N 1196.05N 1248.85N 1298.81N 1345.88N 1389.99N 1431.10N 1469.15N O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE 0.88W 3.51W 7.89W 14.01W 21. 86W 31.43W 42.68W 55.62W 70.20W 86.41W 104.20W 123.56W 144.43W 166.79W 190.58W 215.77W 242.30W 250.30W 256.02W 393.84W 443.42W 448.95W 476.19W 502.93W 529.15W 554.81W 579.88W 604.34W 628.14W 651. 27W 673.69W e PROPOSAL LISTING Page 1 Your ref KBU33-6X Version 2 Last revised 3-0ct-2003 Dogleg Deg/100ft Vert Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.50 2.50 2.50 2.50 2.50 2.50 8.71 19.59 34.78 54.27 78.01 G RID Easting 0.00 0.00 275050.00 275050.00 COORDS Northing 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362050.00 2362052.01 2362058.05 2362068.10 2362082.14 2362100.14 2362122.08 2362147.91 2362177.57 2362211.02 2362248.19 2362289.02 2362333.41 2362381. 29 2362432.56 2362487.14 2362544.90 2362605.76 2362624.11 2362637.24 2362953.34 2363067.06 2363079.73 2363141.14 2363199.91 2363255.97 2363309.25 2363359.69 2363407.22 2363451.78 2363493.33 2363531. 80 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Bottom hole distance is 2259.59 on azimuth 328.01 degrees from wellhead. Total Dogleg for wellpath is 77.64 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.00 0.00 0.00 336.27 336.27 336.27 0.00 0.00 0.00 0.00 0.00 336.27 336.27 336.27 336.27 336.27 0.00 0.00 0.00 0.00 0.00 336.27 336.27 336.27 336.27 336.27 0.00 0.00 0.00 0.00 2.50 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.27 336.17 335.63 335.05 334.42 333.72 332.96 332.11 331.16 330.09 328.86 2.50 2.50 2.50 2.50 2.50 105.96 138.06 174.26 214.49 258.67 2.50 2.50 2.50 2.50 2.50 306.71 358.52 414.01 473.08 535.59 2.50 2.50 0.00 0.00 0.00 601.45 621. 31 635.52 977 . 61 1100.68 2.00 2.00 2.00 2.00 2.00 1114 .40 1181. 06 1245.14 1306.57 1365.27 2.00 2.00 2.QO 2.00 2.00 1421.17 1474.20 1524.30 1571 .41 1615.46 0.00 0.00 0.00 275050.00 275050.00 275050.00 0.00 0.00 0.00 0.00 0.00 275050.00 275050.00 275050.00 275050.00 275050.00 0.00 0.00 0.00 0.00 0.00 275050.00 275050.00 275050.00 275050.00 275050.00 0.00 0.00 0.00 0.00 2.18 275050.00 275050.00 275050.00 275050.00 275049.16 275046.64 275042.46 275036.61 275029.10 275019.96 275009.20 274996.83 274982.89 274967.40 274950.39 274931.89 274911.93 274890.56 274867.82 274843.74 274818.38 274810.73 274805.26 274673.52 274626.12 274620.83 274594.77 274569.16 274544.02 274519.38 274495.28 274471.73 274448.79 274426.46 274404.78 e e MARATHON Oil Company PROPOSAL LISTING Page 2 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised 3-0ct-2003 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C OORDS Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 5200.00 23.33 327.45 4679.26 1504.10N 695.37W 2.00 1656.41 274383.77 2363567.16 5300.00 21.43 325.80 4771.72 1535.91N 716.30W 2.00 1694.20 274363.46 2363599.36 5400.00 19.55 323.84 4865.39 1564.52N 736.44W 2.00 1728.79 274343.88 2363628.36 5500.00 17.69 321.50 4960.16 1589.92N 755.77W 2.00 1760.14 274325.04 2363654.13 5600.00 15.86 318.62 5055.90 1612.07N 774.26W 2.00 1788.20 274306.98 2363676.63 5700.00 14.09 315.03 5152.50 1630.94N 791.90W 2.00 1812.95 274289.71 2363695.83 5800.00 12.38 310.45 5249.85 1646.51N 808.66W 2.00 1834.35 274273.25 2363711.72 5800.16 12.38 310.44 5250.00 1646.53N 808.69W 2.00 1834.38 274273.22 2363711.74 5897.55 10.81 304.65 5345.40 1658.49N 824.14W 2.00 1851.98 274258.00 2363724.00 5900.00 10.81 304.65 5347.81 1658.75N 824.52W 0.00 1852.38 274257.63 2363724.27 6000.00 10.81 304.65 5446.04 1669.42N 839.95W 0.00 1868.79 274242.41 2363735.23 6100.00 10.81 304.65 5544.26 1680.08N 855.38W 0.00 1885.21 274227.19 2363746.19 6200.00 10.81 304.65 5642.49 1690.75N 870.81W 0.00 1901. 63 274211.97 2363757.15 6300.00 10.81 304.65 5740.71 1701.41N 886.24W 0.00 1918.04 274196.75 2363768.11 6400.00 10.81 304.65 5838.94 1712.08N 901.67W 0.00 1934.46 274181.53 2363779.07 6500.00 10.81 304.65 5937.16 1722.74N 917.09W 0.00 1950.88 274166.31 2363790.03 6600.00 10.81 304.65 6035.39 1733.41N 932.52W 0.00 1967.29 274151.09 2363800.98 6700.00 10.81 304.65 6133.61 1744.07N 947.95W 0.00 1983.71 274135.87 2363811.94 6800.00 10.81 304.65 6231.84 1754.74N 963.38W 0.00 2000.12 274120.65 2363822.90 6900.00 10.81 304.65 6330.07 1765.40N 978.81W 0.00 2016.54 274105.43 2363833.86 7000.00 10.81 304.65 6428.29 1776.07N 994.24W 0.00 2032.96 274090.21 2363844.82 7100.00 10.81 304.65 6526.52 1786.73N 1009.67W 0.00 2049.37 274074.99 2363855.78 7200.00 10.81 304.65 6624.74 1797.40N 1025.09W 0.00 2065.79 274059.77 2363866.74 7300.00 10.81 304.65 6722.97 1808.06N 1040.52W 0.00 2082.21 274044.55 2363877.70 7400.00 10.81 304.65 6821.19 1818.73N 1055.95W 0.00 2098.62 274029.33 2363888.66 7500.00 10.81 304.65 6919.42 1829.39N 1071.38W 0.00 2115.04 274014.11 2363899.62 7600.00 10.81 304.65 7017.64 1840.06N 1086.81W 0.00 2131.46 273998.89 2363910.58 7700.00 10.81 304.65 7115.87 1850.72N 1102.24W 0.00 2147.88 273983.67 2363921.54 7800.00 10.81 304.65 7214.09 1861. 39N 1117.67W 0.00 2164.29 273968.45 2363932.50 7900.00 10.81 304.65 7312.32 1872.05N 1133.10W 0.00 2180.71 273953.23 2363943.46 8000.00 10.81 304.65 7410.54 1882.72N 1148.53W 0.00 2197.13 273938.01 2363954.42 8100.00 10.81 304.65 7508.77 1893.38N 1163.95W 0.00 2213.54 273922.79 2363965.38 8200.00 10.81 304.65 7606.99 1904.05N 1179.38W 0.00 2229.96 273907.57 2363976.35 8300.00 10.81 304.65 7705.22 1914.71N 1194.81W 0.00 2246.38 273892.35 2363987.31 8315.46 10.81 304.65 7720.40 1916.36N 1197.20W 0.00 2248.92 273890.00 2363989.00 All data in feet unless otherwise stated. Calculation uses mlnlmum curvature method. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Bottom hole distance is 2259.59 on azimuth 328.01 degrees from wellhead. Total Dogleg for wellpath is 77.64 degrees. vertical section is from wellhead on azimuth 333.58 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ e e MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Your ref KBU33-6X Version 2 Last revised, 3-0ct-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 1500.00 1500.00 O.OON O.OOE 13 3/8 Casing 1750.00 1750.00 O.OON O.OOE KOP 3479.23 3319.76 569.41N 250.30W EOB 4179.88 3830.26 1008.75N 443.42W End of Hold 5800.16 5250.00 1646.53N 808.69W 9 5/8 Casing 5897.55 5345.40 1658.49N 824.14W KBU33-6X - T/Mid Beluga - 9/22/03 8315.46 7720.40 1916.36N 1197.20W KBU33-6X - TD - 9/22/03 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE O.OOE O.OOE 1500.00 5800.16 n/a 1500.00 5250.00 7720.40 O.OON 1646.53N 1916.36N O.OOE 808.69W 1197.20W 13 3/8 Casing 9 5/8 Casing 3 1/2 Liner Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- KBU33-6X - T/Mid Bel 274258.000,2363724.000,999.00 KBU33-6X - TD - 9/22 273890.000,2363989.000,999.00 5345.40 7720.40 1658.49N 1916.36N 824.14W 23-Sep-2003 1197.20W 23-Sep-2003 Created by Sutherland For: S Lambe Date plotted: 3-0d-2003 Plot Reference is KBU33-6X Version 2. Coordinales are in feet reference slot KBU33-6X. True Vertical Depths ore reference RKB (Nabors 129). B¡UII BAKER HU_ JNTEQ 560 - 520 - 480 - 440 - 400 - 360 - ^ I 320 - ,........, -+- Q) Q) ..... '--"' 280 - ..c -+- L.- o Z 240 - 280 240 200 -~ / 200 - ...., ~""'...,""" 160 - , ""~600 ""......... 120 - 80 - 40 - o - 40 - 80 - 280 240 200 e e MARATHON Oil Company Structure: Pod 41-7 Well: KBU33-6X field: Kenai Gas Field Location: Kenai Peninsula, Alaska 160 o East (feet) -> 80 120 80 40 40 120 160 \& \\} (Îill' ''" - \ '\ ' \ "" 600 - \ . 2500 \ \\ I \\ \ . l3200 \\ 3300 \ \ ~\'oo \ \ \ \ 3100 \ \ \ '\ 23~0 \ '\ 3200 \ \ \ \ 3000 \220~ \ \ \ . \, 3 ¡,OO \ \ \ 2900 \ 21 DO \ \ \ \, \ \:¡¡800 \ . ~ 2000 \\ \ \ ì \ \ \ \ 1700J00 \ \ "\ \ 1900 \ \ \ \ \ \ \ \ \ 260\1 2800 \ 1800 \ \ \ \ \ \ ~ \, 2700 ì 2500 \ ~ 170 \ \ .\ \ 2600 . \ \\160~ 2400 \ \ \¡ 2500 '-........ ' \ ...... ~ 1 50b \ 2 0 ...... . ~ 2300 \ 4 0 ......,~\.500 \ \, 2300 1 40<\ \ \ \ ~ 2200 \ 'J. \ 2200 \, 2100 ~ 1 3~\B400 \, 2000 \ '\. @ 1000 . 1200 \...... \ 2~rg300 1100 \ '\.. 1000 \ " 8200 ~~ ~000\8100 ~ \:" -" I I I I I I 80 40 0 40 '~ \ \ \ 2200 \ \ \ \ \ \ \ ì ì \ \ 2100 \ \ \ \ \ 2000 \ "" \. \ \ 1800 \ \ 1700 \ \ \ \ \ ~ 1600 \ \ \ 1500 \ \ ~ 1400 \ \ \'" \ \ 160 120 East (feet) -> 80 120 160 ~ ~ 360 2500/1/) _ 1~00 - 320 ! - /23 9400 - 280 I / /'/"" ~ 1 DO, 3200 / , ! í 200; 3100 1900 13000 , f 1800 /2900 /700 /2800 1600 ~:::o 2500 1200~ 1500 2400 2300 ì 2200 ~ 1400 2100 1 yoo j 1000 1300 / ø , [jJ /. - 80 /1 500 - / ¡. '"0 / /'" I I 200 240 /;;;'000 (!) 200 240 M MARATHON 280 320 - 640 - 600 - 560 - 520 - 480 - 440 - 400 ^ I z o .., -+- :r - 240 ,.-.... - CD CD -+- '--"' - 200 - 160 - 120 - 40 - 0 - 40 - 80 280 320 e MARATHON Oil Company Pad 41-7 KBU33-6X slot KBU33-6X Kenai Gas Field Kenai Peninsula¡ Alaska e 3-D M I N I MUM D I S TAN C E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License KBU33-6X Version 2 prop5527 Date printed Date created Last revised 3-0ct-2003 23-Sep-2003 3-0ct-2003 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on 270916.030,2362063.980,999.00000,N Slot location is n60 27 34.652,w151 14 46.367 Slot Grid coordinates are N 2362050.001, E 275050.000 Slot local coordinates are 65.69 N 4133.64 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet Object wellpath DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* MSS <0-4453'>"KU21-7,Pad 14-6 PMSS <0 - ????>"KBU24-6,Pad 14-6 GMS <0-7375'>"KBU31-7,Pad 14-6 PMSS <5814 - 7575'>,,31-7Rd,Pad 14-6 WD-2 Version #1"WD-2,Pad 14-6 GMS <0-6950'>"KBU23X-6,Pad 14-6 MSS <0-5500'>"KU13-6,Pad 14-6 MSS <0-9895'>"KDU-1,Pad 14-6 MSS <0-6530'>"KU43-12,Pad 14-6 PMSS <O-???'>"KU 31-7,Pad 14-6 INCLINATION ONLY"KU14-6,Pad 14-6 GMS <0 - 9500>"KU14X-6,Pad 14-6 MSS <9776 - 10225>"KU14X-6,Pad 14-6 KU14X-6RD Version #1"KU14X-6Rd,Pad 14-6 MSS <9768 - 10217> DepthShifted"KU14X-6,Pad 1 GMS <0 - 9492> DepthShifted 12/10/02"KU14X-6, PGMS <778 - 5650>"KU21-6X,Pad #? MSS <0 - 5678'> Depth Shifted"KU21-6X,Pad #? MWD <3452 - 5650'>"KU21-6X,Pad #? PGMS <0-3300'>"WD-1,Pad #? MSS <0-4459'>"KUll-6,Pad #? Incl. only <0-5809'>"KU34-31,Pad #? GMS <0-10502'>"KDU5,Pad #? PGMS <0-5700'>"KU14-32,Pad #? GMS <0-11095'>"KDU6,Pad #? Closest approach with 3-D Last revised Distance 12-May-1995 2385.0 12-Mar-2001 1261.6 14-Sep-1995 2186.1 28-Sep-1995 2186.1 26-Mar-1999 2948.2 12-May-1995 1571.4 12-May-1995 2875.0 12-May-1995 1489.0 12-May-1995 3166.9 10-Jan-2001 1454.2 26-Mar-1999 2658.1 11-Dec-2002 2479.9 11-Dec-2002 2479.9 11-Dec-2002 2340.9 11-Dec-2002 2479.9 11-Dec-2002 2479.9 11-Jan-2002 3398.9 18-0ct-2001 3295.7 18-0ct-2001 3417.4 30-May-1995 5883.7 30-May-1995 4295.5 30-May-1995 5497.4 30-May-1995 2834.7 30-May-1995 4603.3 30-May-1995 6350.4 Minimum Distance method M.D. 4237.5 7100.0 3580.0 3580.0 4212.5 7300.0 300.0 8315.5 0.0 3680.0 8315.5 6600.0 6600.0 4875.0 6600.0 6600.0 6000.0 6000.0 6000.0 5550.0 5750.0 7400.0 8315.5 6100.0 5869.7 Diverging from M.D. 4237.5 7100.0 3580.0 3580.0 4212.5 7300.0 4637.5 8315.5 0.0 3680.0 8315.5 6600.0 6600.0 5450.0 6600.0 6600.0 6000.0 6000.0 6000.0 5550.0 5750.0 7400.0 8315.5 6100.0 5869.7 e MMS <0-7910'>"KBU33-7,Pad #?? GMS <0-5820'>, ,KU24-7,Pad #?? MWD <0 - 11857'>, ,KTU32-7H,Pad 41-7 MSS <4305 - 5701>"KU43-6,Pad 41-7 MWD <4250 - 5740>"KU43-6RD,Pad 41-7 KTU43-6XRd Ver.7,,43-6X Rd,Pad 41-7 PGMS <0-8370'>,,43-6,Pad 41-7 PMSS <7670-9464'>,,43-6X Rd,Pad 41-7 PMSS <0-8864>"KTU32-7,Pad 41-7 MSS <0-5300'>,,43-6A,Pad 41-7 MSS <0-10522'>"KDU#2,Pad 41-7 GMS <0-8120'>"KU13-5,Pad 41-7 GMS <0-7902'>"KBU33-6,Pad 41-7 PMSS <8846 - 10960>"KTU24-6H,Pad 41-7 GMS <0-5900'>"KU24-5,Pad 41-7 GMS <0-5350'>"KUll-8,Pad 41-7 PMSS <0 - 7570>"KBU42-7,Pad 41-7 MSS <0-5707'>"KU 43-7,Pad 41-7 GMS <0-5549'>"KDU4,Pad 41-7 MSS <4320 - 10810'>"KDU4Rd,Pad 41-7 MWD <3470 - 4816>"KU24-5Rd,Pad 41-7 MWD <0-7440>"KBU 44-6,Pad 41-7 GMS <0-7290>"KBU41-7,Pad 41-7 KBU43-7X Ver 3"KBU43-7X,Pad 41-7 MWD <0-8610>, ,KBU43-7X,Pad 41-7 MWD <0-5300>, ,KBU41-7X,Pad 41-7 31-May-1995 31-May-1995 17-May-2002 31-Jan-2002 30-Jan-2002 20-Apr-1999 23-Jul-1995 16-Aug-1995 31-Aug-2000 20-Jan-1994 21-Jan-1994 21-Jan-1994 22-Jun-2000 1-Aug-2000 21-Jan-1994 21-Jan-1994 9-Feb-2001 21-Jan-1994 5-May-1995 5-May-1995 9-Jan-2002 3-Mar-2002 13-Mar-2002 6-Jun-2003 13-Jun-2003 19-Mar-2002 4815.4 5787.2 223.9 84.8 84.8 1321.8 61. 7 61. 7 105.4 270.7 414.1 132.5 101. 9 79.8 423.9 450.7 82.3 467.2 319.4 319.4 423.9 173.4 282.2 4235.8 45.5 353.5 7100.0 2200.0 1762.5 1300.0 1300.0 8315.5 2200.0 2200.0 1600.0 1300.0 400.0 1300.0 1100.0 800.0 1000.0 400.0 200.0 200.0 100.0 100.0 1000.0 0.0 1762.5 3150.0 0.0 400.0 e 7100.0 2200.0 1762.5 3980.0 4737.5 8315.5 3412.5 3412.5 1600.0 1300.0 400.0 1300.0 7900.0 8315.5 1000.0 400.0 200.0 200.0 100.0 100.0 1000.0 1775.0 1762.5 3150.0 0.0 1812.5 e e MARATHON Oil Company CLEARANCE LISTING Page 2 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 3-0ct-2003 Reference we11path Object wellpath MSS <4305 - 5701>"KU43-6,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 900.0 900.0 O.ON O.OE 979.2 955.1 116.7S 114.7E 135.5 172.7 181.2 1000.0 1000.0 O.ON O.OE 1075.0 1043.0 78.9S 109.1E 125.9 141.3* 148.7* 1100.0 1100.0 O.ON O.OE 1169.2 1129.4 42.2S 102.3E 112.4 114.5* 118.0* 1200.0 1200.0 O.ON O.OE 1269.0 1217.6 2.0N 87.7E 88.7 89.5* 91.8* 1300.0 1300.0 O.ON O.OE 1353.9 1290.2 43.3N 72.2E 59.1 84.8* 85.5* 1400.0 1400.0 O.ON O.OE 1441.4 1366.3 84.3N 59.5E 35.2 108.5 114.5 1500.0 1500.0 O.ON O.OE 1533.5 1450.4 121.3N 53.3E 23.7 141.5 151.9 1600.0 1600.0 O.ON O.OE 1621. 3 1530.1 157.6N 47.0E 16.6 178.7 195.9 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. e e Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 3 Pad 41-7,KBU33-6X Your ref KBU33-6X version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 3-0ct-2003 Reference wellpath Object wellpath MWD <4250 - 5740>"KU43-6RD,Pad 41-7 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 900.0 900.0 O.ON O.OE 979.2 955.1 116.78 114.7E 135.5 172.7 181.2 1000.0 1000.0 O.ON O.OE 1075.0 1043.0 78.98 109.1E 125.9 141. 3 * 148.7* 1100.0 1100.0 O.ON O.OE 1169.2 1129.4 42.28 102.3E 112.4 114.5* 118.0* 1200.0 1200.0 O.ON O.OE 1269.0 1217.6 2.0N 87.7E 88.7 89.5* 91.8* 1300.0 1300.0 o .ON O.OE 1353.9 1290.2 43.3N 72.2E 59.1 84.8* 85.5* 1400.0 1400.0 o .ON O.OE 1441.4 13 66.3 84.3N 59.5E 35.2 108.5 114.5 1500.0 1500.0 o .ON O.OE 1533.5 1450.4 121.3N 53.3E 23.7 141.5 151.9 1600.0 1600.0 o .ON O.OE 1621. 3 1530.1 157.6N 47.0E 16.6 178.7 195.9 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). e e Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 4 Pad 4l-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised , 3-0ct-2003 Reference wellpath Object wellpath PGM8 <0-8370'>,,43-6,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1600.0 1600.0 o .ON O.OE 1688.7 1648.5 187.08 6.9W 182.1 193.3 199.3 1700.0 1700.0 O.ON O.OE 1790.4 1745.8 159.48 17.0W 186.1 166.7* 173.2* 1750.0 1750.0 o .ON O.OE 1841.9 1794.7 143.98 22.5W 188.9 152.4* 159.1* 1762.5 1762.5 O.ON O.OW 1855.8 1807.8 13 9.68 24.0W 189.8 148.7* 155.2* 1775.0 1775.0 O.lN O.lW 1867.5 1818.8 135.78 25.3W 190.5 145.0* 151. 4* 1787.5 1787.5 0.3N O.lW 1881.2 1831.7 131. 28 26.9W 191.5 141. 3 * 147.6* 1800.0 1800.0 0.5N 0.2W 1893.0 1842.7 127.38 28.2W 192.4 137.6* 143.7* 1812.5 1812.5 0.8N 0.3W 1906.4 1855.2 122.78 29.8W 193.4 133.9* 139.8* 1825.0 1825.0 1.lN 0.5W 1918.2 1866.1 118.68 31. 2W 194.4 130.2* 136.0* 1837.5 1837.5 1.5N 0.7W 1929.9 1877.0 114.48 32.6W 195.4 126.6* 132.1* 1850.0 1850.0 2.0N 0.9W 1943.0 1889.1 109.88 34.2W 196.6 123.0* 128.3* 1862.5 1862.5 2.5N 1.1W 1954.7 1900.0 105.58 35.7W 197.7 119.5* 124.5* 1875.0 1874.9 3.1N 1.4W 1967.7 1911.9 100.88 37.3W 199.1 116.0* 120 .7* 1887.5 1887.4 3.8N 1. 7W 1979.4 1922.7 96.58 38.9W 200.4 112.6* 117.0* 1900.0 1899.9 4.5N 2.0W 1991.2 1933.5 92.18 40.5W 201.7 109.3* 113.4* 1912 . 5 1912.4 5.3N 2.3W 2003.9 1945.1 87.38 42.2W 203.3 106.0* 109.8* 1925.0 1924.8 6.1N 2.7W 2015.7 1955.9 82.88 43.8W 204.8 102.8* 106.3* 1937.5 1937.3 7.0N 3.1W 2027.4 1966.7 78.38 45.4W 206.4 99.7* 102.9* 1950.0 1949.7 8.0N 3.5W 2040.1 1978.2 73.48 47.1W 208.2 96.6* 99.6* 1962.5 1962.2 9.0N 4.0W 2051.9 1988.9 68.88 48.7W 209.9 93.7* 96.4* 1975.0 1974.6 10.lN 4.4W 2063.7 1999.7 64.28 50.3W 211.7 90.8* 93.3* 1987.5 1987.1 11.3N 4.9W 2076.3 2011.1 59.28 52. OW 213.7 88.1* 90.3* 2000.0 1999.5 12.5N 5.5W 2088.1 2021. 9 54.58 53.5W 215.7 85.4* 87.4* 2012.5 2011.9 13.7N 6. OW 2100.8 2033.4 49.48 55.2W 217.9 82.9* 84.6* 2025.0 2024.3 15.1N 6.6W 2112.6 2044.1 44.68 56.7W 220.0 80.4* 82.0* 2037.5 2036.7 16.5N 7.2W 2124.5 2054.8 39.88 58.3W 222.2 78.1* 79.5* 2050.0 2049.1 17.9N 7.9W 2137.2 2066.2 34.68 59.9W 224.7 75.9* 77.1* 2062.5 2061. 5 19.5N 8.6W 2149.0 2076.9 29.68 61. 4W 227.1 73.8* 74.8* 2075.0 2073.9 21.1N 9.3W 2160.9 2087.6 24.68 62.9W 229.6 71.8* 72.7* 2087.5 2086.3 22.7N 10.0W 2173.5 2098.8 19.38 64.5W 232.4 70.0* 70.7* 2100.0 2098.6 24.4N 10.7W 2185.3 2109.4 14 .28 66.0W 235.1 68.3* 68.9* 2112 . 5 2111.0 26.2N 11.5W 2197.5 2120.3 8.98 67.6W 238.0 66.8* 67.3* 2125.0 2123.3 28.0N 12.3W 2209.4 2130.9 3.78 69.0W 240.8 65.4* 65.8* 2137.5 2135.7 29.9N 13 .2W 2221.3 2141.5 1. 5N 70.5W 243.7 64.3* 64.5* 2150.0 2148.0 31. 9N 14.0W 2233.3 2152.2 6.7N 72.0W 246.6 63.4* 63.5* 2162.5 2160.3 33.9N 14.9W 2245.2 2162.8 12.0N 73.5W 249.5 62.7* 62.7* 2175.0 2172.6 36.0N 15.8W 2257.2 2173.4 17.2N 75.0W 252.4 62.1* 62.2* 2187.5 2184.8 38.1N 16.8W 2269.2 2184.1 22.5N 76.6W 255.3 61.8* 61.8* 2200.0 2197.1 40.3N 17.7W 2281.2 2194 . 8 27.7N 78.1W 258.2 61.7* 61.7* 2212.5 2209.4 42.6N 18.7W 2293.2 2205.5 33.0N 79.6W 261.1 61. 7 61. 7 2225.0 2221.6 44.9N 19.7W 2305.5 2216.4 38.4N 81.1W 264.0 61. 9 62.0 2237.5 2233.8 47.3N 20.8W 2317.5 2227.1 43.7N 82.6W 266.7 62.3 62.3 2250.0 2246.0 49.7N 21. 9W 2329.6 2237.8 49. ON 84.1W 269.4 62.8 62.8 2262.5 2258.2 52.2N 23.0W 2341.7 2248.6 54.4N 85.6W 271.9 63.4 63.5 2275.0 2270.4 54.8N 24.1W 2354.3 2259.8 59.9N 87.1W 274.6 64.0 64.2 2287.5 2282.6 57.4N 25.2W 2366.4 2270.6 65.3N 88.5W 277.1 64.8 64.9 2300.0 2294.7 60.1N 26.4W 2378.6 2281.4 70.6N 89.8W 279.4 65.6 65.8 2312.5 2306.9 62.9N 27.6W 2390.7 2292.3 76.0N 91. 2W 281. 6 66.5 66.7 2325.0 2319.0 65.7N 28.9W 2403.1 2303.3 81.4N 92.6W 283.9 67.5 67.7 2337.5 2331.1 68.6N 30.1W 2415.3 2314.2 86.8N 93.9W 286.0 68.5 68.7 2350.0 2343.2 71.5N 31.4W 2427.5 2325.0 92.2N 95.3W 288.0 69.5 69.8 All data is in feet unless otherwise stated. e e Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska Reference wellpath M.D. T.V.D. 2362.5 2375.0 2387.5 2400.0 2412.5 2355.2 2367.3 2379.3 2391.3 2403.3 2425.0 2437.5 2450.0 2462.5 2475.0 2415.3 2427.2 2439.2 2451.1 2463.0 2487.5 2500.0 2512.5 2525.0 2537.5 2474.8 2486.7 2498.5 2510.3 2522.1 2550.0 2562.5 2575.0 2587.5 2600.0 2533.9 2545.6 2557.3 2569.0 2580.6 2612.5 2625 . 0 2637.5 2650.0 2662.5 2592.3 2603.9 2615.5 2627 . 0 2638.6 2675.0 2687.5 2700.0 2712.5 2725.0 2650.1 2661. 6 2673.0 2684.5 2695.9 2737.5 2750.0 2762.5 2775.0 2787.5 2707.2 2718.6 2729.9 2741. 2 2752.4 2800.0 2812.5 2825 . 0 2837.5 2850.0 2763.7 2774.8 2786.0 2797.1 2808.2 2862.5 2875.0 2887.5 2900.0 2912.5 2819.3 2830.4 2841. 4 2852.3 2863.3 2925.0 2937.5 2950.0 2962.5 2975.0 2874.2 2885.1 2895.9 2906.7 2917.5 2987.5 2928 . 2 Rect Coordinates 74.5N 77.5N 80.6N 83.8N 87.1N 90.3N 93.7N 97.1N 100.6N 104.1N 107.7N III . 3N 115. IN 118.8N 122.6N 126.5N 130.5N 134.5N 138.5N 142.7N 146.8N 151.lN 155 AN 159.7N 164.1N 168.6N 173.1N 177 . 7N 182.3N 187.0N 191. 8N 196.6N 201.4N 206.4N 211.3N 216.4N 221.5N 226.6N 231.8N 237.1N 242.4N 247.7N 253.2N 258.6N 264.2N 269.8N 275.4N 281.1N 286.8N 292.6N 298.5N 32.7W 34.1W 35.4W 36.8W 38.3W 39.7W 41. 2W 42.7W 44.2W 45.8W 47.3W 48.9W 50.6W 52.2W 53.9W 55.6W 57.4W 59.1W 60.9W 62.7W 64.5W 66.4W 68.3W 70.2W 72.1W 74.1W 76.1W 78.1W 80.1W 82.2W 84.3W 86.4W 88.5W 90.7W 92.9W 95.1W 97.3W 99.6W 101.9W 104.2W 106.5W 108.9W 111.3W 113.7W 116.1W 118.6W 121.1W 123.6W 126.1W 128.6W 131.2W Obj ect we11path 2439.7 2451.8 2464.1 2476.3 2488.6 2500.9 2513.2 2525.4 2537.7 2550.3 2562.6 2574.9 2587.2 2599.6 2611.9 2624.3 2636.6 2648.7 2661. 0 2673.4 2685.8 2697.8 2710.2 2722.6 2735.0 2747.4 2759.4 2771.8 2784.2 2796.6 2808.6 2821.0 2833.5 2845.9 2858.1 2870.5 2882.9 2895.3 2907.5 2919.9 2932.3 2944.8 2956.8 2969.3 2981.7 2994.1 3006.2 3018.6 3031.0 3043.5 3055.6 M.D. T.V.D. 2335.9 2346.7 2357.6 2368.5 2379.4 2390.3 2401. 2 2412.2 2423.1 2434.2 2445.2 2456.1 2467.1 2478.0 2489.0 2500.0 2510.9 2521. 6 2532.6 2543.5 2554.5 2565.1 2576.0 2587.0 2597.9 2608.8 2619.3 2630.2 2641. 1 2652.0 2662.6 2673.5 2684.3 2695.2 2705.9 2716.8 2727.6 2738.5 2749.1 2760.0 2770.9 2781.7 2792 .2 2803.1 2813.9 2824.7 2835.3 2846.1 2856.8 2867.6 2878.2 CLEARANCE LISTING Page 5 Your ref KBU33-6X Version 2 Last revised, 3-0ct-2003 PGMS <0-8370'>,,43-6,Pad 41-7 Rect Coordinates 97.6N 102.9N 108.3N 113.8N 119.2N 124.7N 130.1N 135.6N 141. IN 146.6N 152.1N 157.6N 163.1N 168.6N 174.1N 179.7N 185.2N 190.7N 196.3N 201.9N 207.6N 213 . IN 218.8N 224.5N 230.2N 236.0N 241.6N 247.4N 253.2N 259. ON 264.7N 270.6N 276.5N 282.3N 288.1N 294.0N 299.9N 305.8N 311.6N 317.5N 323.5N 329.4N 335.2N 341.2N 347 .2N 353 . 2N 359.1N 365.1N 371 . 2N 377.2N 383.1N 96 .6W 97.9W 99.3W 100.6W 102.0W 103.4W 104.7W 106.1W 107.4W 108.7W 110. OW 111.3W 112.6W 113.9W 115.2W 116.4W 117.7W 118.9W 120.1W 121.4W 122.6W 123.8W 125.0W 126.2W 127.4W 128.5W 129.7W 130.8W 132. OW 133.1W 134.3W 135.4W 136.5W 13 7 . 7W 138.8W 13 9 . 9W 141.1W 142 .2W 143.4W 144 . 5W 145 . 6W 146.7W 14 7 . 8W 148.9W 150. OW 151.lW 152.1W 153.2W 154.2W 155.3W 156.3W Horiz Bearing 289.9 291. 7 293.5 295.1 296.8 298.3 299.8 301. 3 302.7 304.0 305.3 306.6 307.8 308.9 310.0 311.1 312.2 313 .2 314 .3 315.3 316.3 317.2 318.2 319.2 320.1 321.1 321.9 322.9 323.8 324.7 325.6 326.5 327.4 328.3 329.1 330.0 330.9 331.7 332.5 333.4 334.3 335.1 336.0 336.9 337.8 338.7 339.6 340.6 341.5 342.5 343.5 MinIm Dist TCyl Dist 70.6 71.7 72.9 74.1 75.3 70.9 72 .1 73.2 74.5 75.7 76.5 77.7 78.9 80.1 81. 3 76.9 78.1 79.3 80.5 81.6 82.4 83.5 84.6 85.6 86.6 82.7 83.8 84.9 85.9 86.9 87.6 88.5 89.5 90.4 91.3 87.9 88.8 89.7 90.6 91.5 92.1 93.0 93.8 94.5 95.3 92.3 93.2 93.9 94.7 95.4 96.0 96.7 97.3 97.9 98.5 96 .1 96.8 97.4 98.0 98.6 99.0 99.6 100.0 100.5 100.8 99.1 99.6 100.1 100.5 100.9 101. 2 101.5 101.7 102.0 102.1 101.2 101. 5 101. 8 102.0 102.1 102.3 102.4 102.4 102.4 102.4* 102.3 102.4 102.4 102.4 102.4* 102.3* 102.2* 102.1* 101.9* 101.7* 102.3* 102.2* 102.1* 101.9* 101.7* 101.5* 101.5* e e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska M.D. Reference wellpath Rect Coordinates T.V.D. 3000.0 3012.5 3025.0 3037.5 3050.0 2938.9 2949.6 2960.2 2970.8 2981.4 3062.5 3075.0 3087.5 3100.0 3112 .5 2991. 9 3002.4 3012.9 3023.3 3033.6 3125.0 3137.5 3150.0 3162.5 3175.0 3044.0 3054.3 3064.5 3074.8 3084.9 3187.5 3200.0 3212.5 3225.0 3237.5 3095.1 3105.2 3115.2 3125.3 3135.2 3250.0 3262.5 3275.0 3287.5 3300.0 3145.2 3155.1 3164.9 3174.7 3184.5 3312.5 3325.0 3337.5 3350.0 3362.5 3194.2 3203.9 3213.6 3223.2 3232.7 3375.0 3387.5 3400.0 3412.5 3425.0 3242.2 3251.7 3261.1 3270.5 3279.8 3437.5 3450.0 3459.7 3469.5 3479.2 3289.1 3298.3 3305.5 3312.6 3319.8 3500.0 3600.0 3700.0 3800.0 3900.0 3334.9 3407.8 3480.6 3553.5 3626.3 4000.0 3699.2 304.4N 310.4N 316.4N 322.5N 328.6N 334.8N 341.0N 347.3N 353.6N 360.0N 366.4N 372.9N 379.4N 386. ON 392.7N 399.4N 406.1N 412.9N 419.7N 426.6N 433.6N 440.6N 447.6N 454.7N 461.8N 469.0N 476.2N 483.5N 490.9N 498 . 2N 505.7N 513 .1N 520.7N 528.2N 535.8N 543.5N 551. 2N 557.3N 563.3N 569.4N 582.4N 645.1N 707.8N 770.5N 833.3N 896.0N 133.8W 136.4W 139.1W 141.7W 144.4W 147.1W 149.9W 152.6W 155.4W 158.2W 161.1W 163.9W 166.8W 169.7W 172.6W 175.5W 178.5W 181. 5W 184.5W 187.5W 190.6W 193.7W 196.7W 199.9W 203.0W 206.2W 209.3W 212.5W 215.8W 219. OW 222.3W 225.6W 228.9W 232.2W 235.5W 238.9W 242.3W 245.0W 247.6W 250.3W 256.0W 283.6W 311.1W 338.7W 366.3W 393.8W Obj ect wellpath 3068.0 3080.4 3092.8 3105.4 3117.8 3130.1 3142.9 3155.3 3168.1 3180.4 3192.7 3205.2 3217.5 3229.8 3242.1 3254.4 3266.7 3278.9 3291. 2 3303.2 3315.4 3327.6 3339.8 3351. 6 3363.8 3375.9 3388.1 3399.9 3412.0 3424.1 3436.2 3448.1 3460.2 3472.2 3484.2 3496 .1 3508.1 3517.4 3526.8 3536.1 3555.9 3650.9 3746.0 3841. 5 3936.6 4031. 3 M.D. T.V.D. 2889.0 2899.8 2910.6 2921. 4 2932.2 2943.0 2954.1 2964.9 2976.0 2986.8 2997.6 3008.5 3019.2 3030.0 3040.8 3051.5 3062.2 3072.9 3083.7 3094.2 3104.9 3115.5 3126.2 3136.4 3147.0 3157.7 3168.2 3178.5 3189.1 3199.6 3210.2 3220.5 3231.0 3241.5 3251.9 3262.3 3272.7 3280.8 3289.0 3297.1 3314.3 3397.0 3479.8 3562.5 3645.1 3727.7 CLEARANCE LISTING Page 6 Your ref KBU33-6X Version 2 Last revised, 3-0ct-2003 PGMS <0-8370'>,,43-6,Pad 41-7 Rect Coordinates 389.2N 395.2N 401. 3N 407.4N 413.4N 419.5N 425.7N 431. 7N 437.8N 443.8N 449.7N 455.7N 461.6N 467.5N 473.4N 479.3N 485.2N 491 . IN 497.0N 502.8N 508.6N 514.5N 520.4N 526.1N 532.0N 537.9N 543.8N 549.6N 555.5N 561. 5N 567.4N 573.2N 579.1N 585.0N 590.9N 596 . 7N 602.6N 607.1N 611 . 7N 616.3N 626.0N 672.5N 719.2N 766.7N 813 . 7N 859.7N 157.4W 158.5W 159 . 5W 160.6W 161.7W 162.7W 163.7W 164.6W 165.6W 166.5W 167.3W 168.2W 169.0W 169.9W 170.7W 171 . 5W 172.3W 173.2W 174.0W 174.8W 175.6W 176.4W 177.2W 178.0W 178.7W 179.5W 180.2W 181. OW 181.7W 182.4W 183.1W 183.7W 184.4W 185.1W 185.7W 186.3W 187.0W 187.4W 187.9W 188.4W 189.4W 194.2W 198.4W 202.5W 206.6W 210.3W Horiz Bearing 344.4 345.4 346.4 347.5 348.5 349.6 350.7 351.9 353.1 354.4 355.7 357.0 358.4 359.9 1.4 101.2 101.2* 100.8* 100.5* 100.1* 99.6* 2.9 4.5 6.1 7.7 9.5 11.3 13 .1 15.0 17.0 19.1 21.2 23.3 25.5 27.8 30.1 32.4 34.8 37.3 39.7 42.2 44.7 47.1 49.1 51.0 52.9 56.8 73.0 84.2 91. 6 97.0 82.2 94.1 113.3 136.5 161. 9 189.2 Min'm Dist TCyl Dist 101. 2 * 100.9* 100.5* 100.1* 99.7* 99.1* 98.5* 97.8* 97.1* 96.4* 99.2* 98.6* 98.0* 97.3* 96.6* 95.6* 94.7* 93.9* 93.0* 92.1* 95.8* 95.0* 94.1* 93.2* 92.3* 91. 2 * 90.2* 89.3* 88.4* 87.4* 91.4* 90.5* 89.6* 88.6* 87.7* 86.5* 85.6* 84.8* 84.0* 83.2* 86.8* 85.9* 85.0* 84.1* 83.3* 82.5* 81.8* 81.2* 80.7* 80.2* 82.6* 81.9* 81. 3 * 80.7* 80.3* 79.8* 79.5* 79.4* 79.3* 79.3 79.9* 79.6* 79.4* 79.3* 79.3 79.4 79.7 80.0 80.4 80.9 79.5 79.8 80.1 80.5 81.0 82.4 95.4 116.2 140.9 168.1 196.9 - e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field/Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 1600.0 1700.0 1750.0 1762.5 1775.0 1600.0 1700.0 1750.0 1762.5 1775.0 1787.5 1800.0 1812.5 1825.0 1837.5 1787.5 1800.0 1812.5 1825.0 1837.5 1850.0 1862.5 1875.0 1887.5 1900.0 1850.0 1862.5 1874.9 1887.4 1899.9 1912.5 1925.0 1937.5 1950.0 1962 .5 1912.4 1924.8 1937.3 1949.7 1962.2 1975.0 1987.5 2000.0 2012.5 1974.6 1987.1 1999.5 2011.9 2025.0 2024.3 2037.5 2050.0 2062.5 2075.0 2087.5 2036.7 2049.1 2061. 5 2073.9 2086.3 2100.0 2112 .5 2125.0 2137.5 2150.0 2098.6 2111 . 0 2123 .3 2135.7 2148.0 2162.5 2175.0 2187.5 2200.0 2212.5 2160.3 2172.6 2184.8 2197.1 2209.4 2225.0 2237.5 2250.0 2262.5 2275.0 2221. 6 2233.8 2246.0 2258.2 2270.4 2287.5 2300.0 2282.6 2294.7 2312.5 2325.0 2337.5 2306.9 2319.0 2331.1 O.ON O.ON o .ON o .ON O.lN 0.3N o .5N o .8N 1.lN 1.5N 2.0N 2.5N 3.1N 3.8N 4.5N 5.3N 6.1N 7.0N 8.0N 9.0N 10.lN 11. 3N 12.5N 13.7N 15.1N 16.5N 17.9N 19.5N 21.1N 22.7N 24.4N 26.2N 28.0N 29.9N 31.9N 33.9N 36.0N 38.1N 40.3N 42.6N 44.9N 47.3N 49.7N 52.2N 54.8N 57.4N 60.1N 62.9N 65.7N 68.6N 7.2W 7.9W 8.6W 9.3W 10.0W 10.7W 11.5W 12.3W 13 .2W 14.0W 14.9W 15.8W 16.8W 17.7W 18.7W 19.7W 20.8W 21.9W 23.0W 24.1W 25.2W 26.4W 27.6W 28.9W 30.1W Object we11path O.OE O.OE O.OE O.OW O.lW 1688.7 1790.4 1841.9 1855.8 1867.5 O.lW 0.2W 0.3W 0.5W 0.7W 1881. 2 1893.0 1906.4 1918.2 1929.9 0.9W 1.1W l.4W 1. 7W 2.0W 1943.0 1954.7 1967.7 1979.4 1991.2 2.3W 2.7W 3.1W 3.5W 4.0W 2003.9 2015.7 2027.4 2040.1 2051. 9 4.4W 4.9W 5.5W 6.0W 2063.7 2076.3 2088.1 2100.8 6.6W 2112.6 2124.5 2137.2 2149.0 2160.9 2173.5 2185.3 2197.5 2209.4 2221.3 2233.3 2245.2 2257.2 2269.·2 2281. 2 2293.2 2305.5 2317.5 2329.6 2341.7 2354.3 2366.4 2378.6 2390.7 2403.1 2415.3 M.D. T.V.D. 1648.5 1745.8 1794.7 1807.8 1818.8 1831.7 1842.7 1855.2 1866.1 1877.0 1889.1 1900.0 1911.9 1922.7 1933.5 1945.1 1955.9 1966.7 1978.2 1988.9 1999.7 2011.1 2021.9 2033.4 2044.1 2054.8 2066.2 2076.9 2087.6 2098.8 2109.4 2120.3 2130.9 2141.5 2152.2 2162.8 2173.4 2184.1 2194.8 2205.5 2216.4 2227.1 2237.8 2248.6 2259.8 2270.6 2281. 4 2292.3 2303.3 2314.2 CLEARANCE LI8TING Page 7 Your ref KBU33-6X Version 2 Last revised, 3-0ct-2003 PM88 <7670-9464'>,,43-6X Rd,Pad 41-7 TCyl Dist Rect Coordinates Horiz MinIm Bearing Dist 187.08 159.48 143.98 13 9.68 135.78 131.28 127.38 122.78 118.68 114.48 109.88 105.58 100.88 96.58 92.18 87.38 82.88 78.38 73.48 68.88 64.28 59.28 54.58 49.48 44.68 39.88 34.68 29.68 24.68 19.38 14.28 8.98 3.78 1.5N 6.7N 12.0N 17.2N 22.5N 27.7N 33.0N 38.4N 43.7N 49.0N 54.4N 59.9N 65.3N 70.6N 76.0N 81.4N 86.8N 6.9W 17.0W 22.5W 24.0W 25.3W 26.9W 28.2W 29.8W 31. 2W 32.6W 34.2W 35.7W 37.3W 38.9W 40.5W 42.2W 43.8W 45.4W 47.1W 48.7W 50.3W 52. OW 53.5W 55.2W 56.7W 58.3W 59.9W 61.4W 62.9W 64.5W 66.0W 67.6W 69.0W 70.5W 72 .OW 73.5W 75.0W 76.6W 78.1W 79.6W 81.1W 82.6W 84.1W 85.6W 87.1W 88.5W 89.8W 91.2W 92.6W 93.9W 182.1 186.1 188.9 189.8 190.5 191.5 192.4 193.4 194.4 195.4 196.6 197.7 199.1 200.4 201.7 203.3 204.8 206.4 208.2 209.9 211.7 213.7 215.7 217.9 220.0 222.2 224.7 227.1 229.6 232.4 235.1 238.0 240.8 243.7 246.6 249.5 252.4 255.3 258.2 261.1 264.0 266.7 269.4 271. 9 274.6 277.1 279.4 281. 6 283.9 286.0 193.3 166.7* 152.4* 148.7* 145.0* 141. 3 * 137.6* 133.9* 130.2* 126.6* 123.0* 119.5* 116.0* 112.6* 109.3* 106.0* 102.8* 99.7* 96.6* 93.7* 199.3 173.2* 159.1* 155.2* 151.4* 147.6* 143.7* 139.8* 136.0* 132.1* 128.3* 124.5* 120.7* 117.0* 113.4* 109.8* 106.3* 102.9* 99.6* 96.4* 90.8* 88.1* 85.4* 82.9* 93.3* 90.3* 87.4* 84.6* 80.4* 82.0* 78.1* 75.9* 73.8* 71.8* 70.0* 79.5* 77.1* 74.8* 72.7* 70.7* 68.3* 66.8* 65.4* 64.3* 63.4* 68.9* 67.3* 65.8* 64.5* 63.5* 62.7* 62.1* 61.8* 61.7* 61. 7 62.7* 62.2* 61.8* 61.7* 61. 7 61. 9 62.3 62.8 63.4 64.0 62.0 62.3 62.8 63.5 64.2 64.8 65.6 64.9 65.8 66.5 67.5 68.5 66.7 67.7 68.7 2350.0 2343.2 71.5N e 31.4W 2427.5 2325.0 92.2N 95.3W 288.0 e 69.5 69.8 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska Reference wellpath M.D. T.V.D. 2362.5 2375.0 2387.5 2400.0 2412.5 2355.2 2367.3 2379.3 2391.3 2403.3 2425.0 2437.5 2450.0 2462.5 2475.0 2415.3 2427.2 2439.2 2451.1 2463.0 2487.5 2500.0 2512.5 2525.0 2537.5 2474.8 2486.7 2498.5 2510.3 2522.1 2550.0 2562.5 2575.0 2587.5 2600.0 2533.9 2545.6 2557.3 2569.0 2580.6 2612.5 2625.0 2637.5 2650.0 2662.5 2592.3 2603.9 2615.5 2627.0 2638.6 2675.0 2687.5 2700.0 2712 .5 2725.0 2650.1 2661. 6 2673.0 2684.5 2695.9 2737.5 2750.0 2762.5 2775.0 2787.5 2707.2 2718.6 2729.9 2741. 2 2752.4 2800.0 2812.5 2825.0 2837.5 2850.0 2763.7 2774.8 2786.0 2797.1 2808.2 2862.5 2875.0 2887.5 2900.0 2912.5 2819.3 2830.4 2841.4 2852.3 2863.3 2925 . 0 2937.5 2950.0 2962.5 2975.0 2874.2 2885.1 2895.9 2906.7 2917.5 Rect Coordinates 74.5N 77.5N 80.6N 83.8N 87.1N 90.3N 93.7N 97.1N 100.6N 104.1N 107.7N 111.3N 115.1N 118.8N 122.6N 126.5N 130.5N 134.5N 138.5N 142 .7N 146.8N 151.1N 155.4N 159.7N 164.1N 168.6N 173.1N 177 . 7N 182.3N 187.0N 191.8N 196.6N 201. 4N 206.4N 211. 3N 216.4N 221. 5N 226.6N 231. 8N 237.1N 242.4N 247.7N 253.2N 258.6N 264.2N 269.8N 275.4N 281.1N 286.8N 292.6N 32.7W 34.1W 35.4W 36.8W 38.3W 39.7W 41.2W 42.7W 44.2W 45.8W 47.3W 48.9W 50.6W 52.2W 53.9W 55.6W 57.4W 59.1W 60.9W 62.7W 64.5W 66.4W 68.3W 70.2W 72.1W 74.1W 76.1W 78.1W 80.1W 82.2W 84.3W 86.4W 88.5W 90.7W 92 .9W 95.1W 97.3W 99.6W 101.9W 104.2W 106.5W 108.9W 111.3W 113.7W 116.1W 118.6W 121.1W 123.6W 126.1W 128.6W Object wellpath 2439.7 2451.8 2464.1 2476.3 2488.6 2500.9 2513 .2 2525.4 2537.7 2550.3 2562.6 2574.9 2587.2 2599.6 2611.9 2624.3 2636.6 2648.7 2661. 0 2673.4 2685.8 2697 . 8 2710.2 2722.6 2735.0 2747.4 2759.4 2771.8 2784.2 2796.6 2808.6 2821. 0 2833.5 2845.9 2858.1 2870.5 2882.9 2895.3 2907.5 2919.9 2932.3 2944.8 2956.8 2969.3 2981.7 2994.1 3006.2 3018.6 3031. 0 3043.5 M.D. T.V.D. 2335.9 2346.7 2357.6 2368.5 2379.4 2390.3 2401.2 2412.2 2423.1 2434.2 2445.2 2456.1 2467.1 2478.0 2489.0 2500.0 2510.9 2521.6 2532.6 2543.5 2554.5 2565.1 2576.0 2587.0 2597.9 2608.8 2619.3 2630.2 2641.1 2652.0 2662.6 2673.5 2684.3 2695.2 2705.9 2716.8 2727.6 2738.5 2749.1 2760.0 2770.9 2781.7 2792.2 2803.1 2813.9 2824.7 2835.3 2846.1 2856.8 2867.6 CLEARANCE LISTING Page 8 Your ref KBU33-6X Version 2 Last revised, 3-0ct-2003 PMSS <7670-9464'>, ,43-6X Rd,Pad 41-7 Rect Coordinates 97.6N 102.9N 108.3N 113.8N 119.2N 124.7N 13 0 . IN 13 5 . 6N 141.1N 146.6N 152.1N 157.6N 163.1N 168.6N 174.1N 179.7N 185.2N 190.7N 196.3N 201.9N 207.6N 213 . IN 218.8N 224.5N 230.2N 236.0N 241.6N 247.4N 253.2N 259. ON 264.7N 270.6N 276.5N 282.3N 288.1N 294 . ON 299.9N 305.8N 311 . 6N 317.5N 323.5N 329.4N 335.2N 341.2N 347.2N 353.2N 359.1N 365.1N 371 . 2N 377.2N 96 .6W 97.9W 99.3W 100.6W 102.0W 103.4W 104.7W 106.1W 107.4W 108.7W 110.0W 111. 3W 112.6W 113.9W 115.2W 116.4W 11 7 . 7W 118.9W 120.1W 121.4W 122.6W 123.8W 125.0W 126.2W 127.4W 128.5W 129.7W 130.8W 132. OW 133.1W 134.3W 135.4W 136.5W 13 7 . 7W 138.8W 13 9 . 9W 141.1W 142 .2W 143.4W 144 . 5W 145.6W 146.7W 14 7 . 8W 148.9W 150.0W 151.1W 152.1W 153.2W 154.2W 155.3W Horiz Bearing 289.9 291.7 293.5 295.1 296.8 298.3 299.8 301. 3 302.7 304.0 305.3 306.6 307.8 308.9 310.0 311.1 312.2 313 .2 314.3 315.3 316.3 317.2 318.2 319.2 320.1 321.1 321. 9 322.9 323.8 324.7 325.6 326.5 327.4 328.3 329.1 330.0 330.9 331.7 332.5 333.4 334.3 335.1 336.0 336.9 337.8 338.7 339.6 340.6 341.5 342.5 MinIm Dist TCyl Dist 70.6 71.7 72.9 74.1 75.3 70.9 72.1 73.2 74.5 75.7 76.5 77.7 78.9 80.1 81.3 76.9 78.1 79.3 80.5 81. 6 82.4 83.5 84.6 85.6 86.6 82.7 83.8 84.9 85.9 86.9 87.6 88.5 89.5 90.4 91.3 87.9 88.8 89.7 90.6 91.5 92.1 93.0 93.8 94.5 95.3 92.3 93.2 93.9 94.7 95.4 96.0 96.7 97.3 97.9 98.5 96.1 96.8 97.4 98.0 98.6 99.0 99.6 100.0 100.5 100.8 99.1 99.6 100.1 100.5 100.9 101. 2 101.5 101.7 102.0 102.1 101. 2 101.5 101.8 102.0 102.1 102.3 102.4 102.4 102.4 102.4* 102.3 102.4 102.4 102.4 102.4* 102.3* 102.2* 102.1* 101.9* 101.7* 102.3* 102.2* 102.1* 101.9* 101.7* e e 2987.5 2928 .2 298.5N 131.2W 3055.6 2878.2 383.1N 156.3W 343.5 101.5* 101. 5* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LISTING Page 9 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field, Kenai Peninsula, Alaska Last revised , 3-0ct-2003 Reference wellpath Object wellpath PMSS <7670-9464'>,,43-6X Rd,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 3000.0 2938.9 304.4N 13 3 . 8W 3068.0 2889.0 389.2N 157.4W 344.4 101.2* 101. 2* 3012.5 2949.6 310.4N 13 6. 4W 3080.4 2899.8 395.2N 158.5W 345.4 100.8* 100.9* 3025.0 2960.2 316.4N 13 9 .IW 3092.8 2910.6 401.3N 159.5W 346.4 100.5* 100.5* 3037.5 2970.8 322.5N 141.7W 3105.4 2921. 4 407.4N 160.6W 347.5 100.1* 100.1* 3050.0 2981.4 328.6N 144.4W 3117.8 2932.2 413.4N 161.7W 348.5 99.6* 99.7* 3062.5 2991.9 334.8N 147.1W 3130.1 2943.0 419.5N 162.7W 349.6 99.1* 99.2* 3075.0 3002.4 341.0N 149.9W 3142.9 2954.1 425.7N 163.7W 350.7 98.5* 98.6* 3087.5 3012.9 347.3N 152.6W 3155.3 2964.9 431.7N 164.6W 351. 9 97.8* 98.0* 3100.0 3023.3 353.6N 155.4W 3168.1 2976.0 437.8N 165.6W 353.1 97.1* 97.3* 3112 .5 3033.6 360.0N 158.2W 3180.4 2986.8 443.8N 166.5W 354.4 96.4* 96.6* 3125.0 3044.0 366.4N 161.1W 3192.7 2997.6 449.7N 167.3W 355.7 95.6* 95.8* 3137.5 3054.3 372 . 9N 163.9W 3205.2 3008.5 455.7N 168.2W 357.0 94.7* 95.0* 3150.0 3064.5 379.4N 166.8W 3217.5 3019.2 461.6N 169.0W 358.4 93.9* 94.1* 3162.5 3074.8 386.0N 169.7W 3229.8 3030.0 467.5N 169.9W 359.9 93.0* 93.2* 3175.0 3084.9 392.7N 172.6W 3242.1 3040.8 473.4N 170.7W 1.4 92.1* 92.3* 3187.5 3095.1 399.4N 175.5W 3254.4 3051.5 479.3N 171 . 5W 2.9 91.2* 91. 4 * 3200.0 3105.2 406.1N 178.5W 3266.7 3062.2 485.2N 172.3W 4.5 90.2* 90.5* 3212.5 3115.2 412.9N 181.5W 3278.9 3072.9 491.1N 173.2W 6.1 89.3* 89.6* 3225.0 3125.3 419.7N 184.5W 3291.2 3083.7 497.0N 174.0W 7.7 88.4* 88.6* 3237.5 3135.2 426.6N 187.5W 3303.2 3094.2 502.8N 174.8W 9.5 87.4* 87.7* 3250.0 3145.2 433.6N 190.6W 3315.4 3104.9 508.6N 175.6W 11.3 86.5* 86.8* 3262.5 3155.1 440.6N 193.7W 3327.6 3115.5 514 . 5N 176.4W 13 .1 85.6* 85.9* 3275.0 3164.9 447.6N 196.7W 3339.8 3126.2 520.4N 177 . 2W 15.0 84.8* 85.0* 3287.5 3174.7 454.7N 199.9W 3351. 6 3136.4 526.1N 178.0W 17.0 84.0* 84.1* 3300.0 3184.5 461.8N 203.0W 3363.8 3147.0 532.0N 178.7W 19.1 83.2* 83.3* 3312.5 3194.2 469.0N 206.2W 3375.9 3157.7 537.9N 179.5W 21.2 82.5* 82.6* 3325.0 3203.9 476.2N 209.3W 3388.1 3168.2 543.8N 180.2W 23.3 81.8* 81.9* 3337.5 3213.6 483.5N 212.5W 3399.9 3178.5 549.6N 181. OW 25.5 81.2* 81. 3 * 3350.0 3223.2 490.9N 215.8W 3412.0 3189.1 555.5N 181.7W 27.8 80.7* 80.7* 3362.5 3232.7 498.2N 219.0W 3424.1 3199.6 561. 5N 182.4W 30.1 80.2* 80.3* 3375.0 3242.2 505.7N 222.3W 3436.2 3210.2 567.4N 183.1W 32.4 79.8* 79.9* 3387.5 3251.7 513 .IN 225.6W 3448.1 3220.5 573.2N 183.7W 34.8 79.5* 79.6* 3400.0 3261.1 520.7N 228.9W 3460.2 3231.0 579.1N 184.4W 37.3 79.4* 79.4* 3412.5 3270.5 528 .2N 232.2W 3472.2 3241.5 585.0N 185.1W 39.7 79.3* 79.3* 3425.0 3279.8 535.8N 235.5W 3484.2 3251. 9 590.9N 185.7W 42.2 79.3 79.3 3437.5 3289.1 543.5N 238.9W 3496 .1 3262.3 596 . 7N 186.3W 44.7 79.4 79.5 3450.0 3298.3 551.2N 242.3W 3508.1 3272.7 602.6N 187.0W 47.1 79.7 79.8 3459.7 3305.5 557.3N 245.0W 3517.4 3280.8 607.1N 187.4W 49.1 80.0 80.1 3469.5 3312.6 563.3N 247.6W 3526.8 3289.0 611.7N 187.9W 51. 0 80.4 80.5 3479.2 3319.8 569.4N 250.3W 3536.1 3297.1 616.3N 188.4W 52.9 80.9 81. 0 3500.0 3334.9 582.4N 256.0W 3555.9 3314 . 3 626.0N 189.4W 56.8 82.2 82.4 3600.0 3407.8 645.1N 283.6W 3650.9 3397.0 672.5N 194.2W 73.0 94.1 95.4 3700.0 3480.6 707.8N 311.1W 3746.0 3479.8 719.2N 198.4W 84.2 113.3 116.2 3800.0 3553.5 770.5N 338.7W 3841. 5 3562.5 766.7N 202.5W 91. 6 136.5 140.9 3900.0 3626.3 833.3N 366.3W 3936.6 3645.1 813 .7N 206.6W 97.0 161.9 168.1 4000.0 3699.2 896. ON 393.8W 4031. 3 3727.7 859.7N 210.3W 101.2 189.2 196.9 e e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1750.0 1762.5 1500.0 1600.0 1700.0 1750.0 1762.5 1775.0 1787.5 1800.0 1812.5 1825.0 1775.0 1787.5 1800.0 1812.5 1825.0 1837.5 1850.0 1862.5 1875.0 1887.5 1837.5 1850.0 1862.5 1874.9 1887.4 1900.0 1912.5 1925.0 1937.5 1950.0 1899.9 1912 .4 1924.8 1937.3 1949.7 1962.5 1975.0 1987.5 2000.0 2012.5 1962.2 1974.6 1987.1 1999.5 2011.9 2025.0 2037.5 2050.0 2062.5 2075.0 2024.3 2036.7 2049.1 2061.5 2073.9 2087.5 2100.0 2112.5 2086.3 2098.6 2111.0 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON o .ON o .ON o .ON o .ON o .ON o .ON o .ON O.ON O.ON O.ON O.ON O.lN 0.3N 0.5N 0.8N 1. IN 1.5N 2.0N 2.5N 3.1N 3.8N 4.5N 5.3N 6.1N 7.0N 8.0N 9.0N 10.lN 11.3N 12.5N 13.7N 15. IN 16.5N 17.9N 19.5N 21.1N 22.7N 24.4N 26.2N 10.0W 10.7W 11.5W Object wellpath O.OE O.OE O.OE O.OE O.OE 4.7 105.0 205.3 305.7 406.5 O.OE O.OE O.OE O.OE O.OE 507.2 607.3 707.5 807.4 906.8 O.OE O.OE O.OE O.OE O.OE 1006.7 1106.8 1207.0 1307.1 1407.3 O.OE O.OE O.OE O.OE O.OW 1507.4 1604.9 1701. 3 1750.2 1762.6 O.lW O.lW 0.2W 0.3W 0.5W 1774.1 1786.5 1798.9 1810.2 1822.6 0.7W 0.9W 1.1W 1.4W 1. 7W 1833.8 1846.1 1858.4 1869.4 1881. 6 2.0W 2.3W 2.7W 3.1W 3.5W 1893.9 1904.8 1917.0 1927.8 1939.9 4.0W 4.4W 4.9W 5.5W 6. OW 1952.1 1962.7 1974.8 1985.1 1997.1 6.6W 7.2W 7.9W 8.6W 9.3W 2007.1 2019.0 2030.9 2040.6 2052.4 2064.2 2074.1 2085.7 M.D. T.V.D. 0.1 100.4 200.7 301.0 401.9 502.6 602.7 702.7 802.4 901.6 1001.3 1101.4 1201. 6 1301.6 1401. 9 1502.0 1599.4 1695.6 1744.2 1756.6 1768.0 1780.3 1792.6 1803.8 1816.1 1827.2 1839.4 1851.6 1862.5 1874.6 1886.7 1897.5 1909.5 1920.2 1932.1 1944.0 1954.5 1966.4 1976.5 1988.3 1998.1 2009.7 2021.3 2030.8 2042.3 2053.7 2063.4 2074.7 CLEARANCE LI8TING Page 10 Your ref KBU33-6X Version 2 Last revised: 3-0ct-2003 PM88 <0-8864>"KTU32-7,Pad 41-7 Rect Coordinates 82.08 81.78 80.78 79.48 78.08 77.08 77.28 78.98 82.18 85.08 87.28 88.48 88.48 87.68 86.18 84.58 84.28 89.88 93.88 95.08 96 .18 97.38 98.68 99.98 101.38 102.68 104.18 105.78 107.28 108.88 110.68 112.28 114.08 115.78 11 7.78 119.78 121. 58 123.68 125.58 127.78 129.68 131 . 98 134.38 136.48 13 8 . 98 141.48 143.68 146.38 97.6E 97.7E 98.0E 98.2E 98.0E 96 .4E 93.5E 89.1E 83.2E 77.7E 73.3E 69.9E 67.7E 66.5E 65.8E 64.9E 63.5E 59.7E 57.4E 56.8E 56.2E 55.6E 54.9E 54.3E 53.6E 53.0E 52.3E 51.6E 51.0E 50.3E 49.6E 48.9E 48.2E 47.5E 46.8E 46.0E 45.3E 44.5E 43.9E 43.1E 42.4E 41.6E 40.7E 40.1E 39.2E 38.4E 37.6E 36.8E Horiz Bearing 130.0 129.9 129.5 129.0 128.5 128.6 129.6 131.5 134.6 137.6 139.9 141. 7 142.5 142.8 142.6 142.5 143.0 146.4 148.5 149.1 149.7 150.3 150.9 151.5 152.1 152.7 153.4 154.0 154.6 155.2 155.9 156.4 157.1 157.6 158.2 158.8 159.3 159.9 160.3 160.9 161.3 161. 8 162.3 162.7 163.1 163.6 163.9 164.4 127.5 127.4* 127.0* 126.3* 125.2* 123.4* 121.3* 119.1* 116.9* 115.2* 113.9* 112.7* 111. 4 * 110.0* 108.4* 106.6* 105.4* 107.9 110.1 110.8 111.7 112.6 113.7 114.9 116.2 117.6 119.2 120.9 122.7 124.7 126.8 129.0 131.3 133.8 136.5 139.2 142.1 145.1 148.3 151. 6 155.0 158.6 162.3 166.1 170.1 174.2 178.4 182.7 MinIm Dist TCyl Dist 127.5 127.4* 127.0* 126.3* 125.2* 123.5* 121.3* 119.1* 116.9* 115.2* 113.9* 112.7* 111.4* 110.0* 108.4* 106.6* 105.4* 108.0 110.3 111.1 112.0 113.0 114.2 115.5 116.9 118.5 120.3 122.2 124.2 126.4 128.8 131.4 134.1 136.9 140.0 143.2 146.6 150.1 153.9 157.9 162.0 166.4 170.9 175.6 180.4 185.5 190.7 196.0 e e 2125.0 2123.3 28.0N 12.3W 2095.9 2084.6 148.68 36.0E 164.7 187.2 201. 6 2137.5 2135.7 29.9N 13 .2W 2107.5 2095.8 151. 38 35.1E 165.1 191.7 207.4 2150.0 2148.0 31. 9N 14 .OW 2117.5 2105.5 153.78 34.3E 165.4 196 .4 213.4 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska CLEARANCE LI8TING Page 11 Your ref KBU33-6X Version 2 Last revised, 3-0ct-2003 Reference wellpath Object wellpath PM88 <0-8864>"KTU32-7,Pad 41-7 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing MinIm Dist TCyl Dist e e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 12 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised 3-0ct-2003 Reference wellpath Object wellpath GM8 <0-8120'>"KU13-5,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 800.0 800.0 O.ON O.OE 835.4 825.0 188.48 51.3E 164.8 196.9 198.4 900.0 900.0 O.ON O.OE 939.3 926.7 170.58 62.0E 160.0 183.4* 185.3* 1000.0 1000.0 O.ON O.OE 1043.0 1027.1 147.78 74.6E 153.2 167.7* 169.9* 1100.0 1100.0 O.ON O.OE 1142 .7 1122.3 121.48 88.0E 144.1 151.6* 153.4* 1200.0 1200.0 O.ON O.OE 1238.6 1213 .4 94.48 100.9E 133.1 138.8* 139.6* 1300.0 1300.0 O.ON O.OE 1333.6 1304.1 68.68 113.3E 121.2 132.5* 132.5* 1400.0 1400.0 O.ON O.OE 1428.7 13 94.3 41. 68 126.2E 108.3 133.0 133.1 1500.0 1500.0 O.ON O.OE 1521.9 1481.8 12.48 13 9. 8E 95.1 141.6 142.9 1600.0 1600.0 O.ON O.OE 1613.8 1567.2 18.2N 154.0E 83.3 158.5 162.4 1700.0 1700.0 O.ON O.OE 1705.4 1652.1 49.6N 168.5E 73.6 182.1 189.3 1750.0 1750.0 O.ON O.OE 1751. 5 1694.7 65.6N 175.9E 69.6 195.8 204.7 1762.5 1762.5 O.ON O.OW 1763.0 1705.3 69.6N 177.8E 68.6 199.3 208.7 e e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level: Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 13 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 3-0ct-2003 Reference wellpath Object wellpath GM8 <0-7902'>, ,KBU33-6,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 4.4 -0.2 82.68 67.4W 219.2 106.6 106.6 100.0 100.0 O.ON O.OE 103.6 99.0 83.08 67.6W 219.2 107.1 107.1 200.0 200.0 O.ON O.OE 203.4 198.8 83.98 68.2W 219.1 108.1 108.1 300.0 300.0 O.ON O.OE 303.3 298.6 84.78 69. OW 219.2 109.3 109.3 400.0 400.0 O.ON O.OE 403.0 398.4 85.68 70.1W 219.3 110.6 110.7 500.0 500.0 O.ON O.OE 502.8 498.1 86.58 71.5W 219.6 112.2 112.2 600.0 600.0 O.ON O.OE 603.4 598.7 86.88 73.6W 220.3 113.8 113.8 700.0 700.0 O.ON O.OE 704.6 699.9 84.58 77 .2W 222.4 114.4 114.4 800.0 800.0 O.ON O.OE 806.2 801. 2 79.88 81.3W 225.5 113.9* 113.9* 900.0 900.0 O.ON O.OE 909.3 903.9 71.38 85.9W 230.3 111.7* 111.7* 1000.0 1000.0 o .ON O.OE 1013.7 1007.0 55.58 90.8W 238.6 106.6* 106.8* 1100.0 1100.0 o .ON O.OE 1111.9 1102.8 34.48 95.9W 250.2 101.9* 101.9* 1200.0 1200.0 o .ON O.OE 1208.6 1196.3 10.88 101.5W 263.9 102.2 102.2 1300.0 1300.0 o .ON O.OE 13 04.0 1287.8 15.6N 107.7W 278.2 109.5 110.2 1400.0 1400.0 o .ON O.OE 13 97.1 1375.8 45.0N 113.7W 291. 6 124.7 127.3 1500.0 1500.0 o .ON O.OE 1489.6 1462.6 76.6N 120 .2W 302.5 147.3 152.7 1600.0 1600.0 o .ON O.OE 1580.7 1547.8 108.1N 127.2W 310.4 174.9 184.6 e e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level) . Total Dogleg for we1lpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 14 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 3-0ct-2003 Reference wellpath Object wellpath PM88 <8846 - 10960>"KTU24-6H,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 4.9 0.3 80.38 32.6E 157.9 86.6 86.6 100.0 100.0 O.ON O.OE 105.4 100.8 79.98 32.1E 158.1 86.1* 86.1* 200.0 200.0 O.ON O.OE 206.0 201. 3 79.08 30.7E 158.8 84.7* 84.7* 300.0 300.0 O.ON O.OE 305.7 301.0 77 .68 28.3E 160.0 82.6* 82.6* 400.0 400.0 O.ON O.OE 405.3 400.6 77.98 24.8E 162.3 81.8* 81.8* 500.0 500.0 O.ON O.OE 505.4 500.6 78.18 21.2E 164.8 81.0* 81.0* 600.0 600.0 O.ON O.OE 605.3 600.5 78.38 17.6E 167.3 80.3* 80.3* 700.0 700.0 O.ON O.OE 705.1 700.2 78.68 14.2E 169.7 79.9* 79.9* 800.0 800.0 O.ON O.OE 804.9 800.0 79.08 1l.lE 172.0 79.8* 79.8* 900.0 900.0 O.ON O.OE 904.8 899.8 79.58 8.2E 174.1 80.0 80.0 1000.0 1000.0 O.ON O.OE 1004.8 999.8 80.08 5.8E 175.8 80.2 80.2 1100.0 1100.0 O.ON O.OE 1104.8 1099.8 80.48 4.5E 176.8 80.5 80.5 1200.0 1200.0 O.ON O.OE 1204.8 1199.8 80.68 3.8E 177.3 80.7 80.7 1300.0 1300.0 O.ON O.OE 1304.6 1299.6 81.08 3.1E 177.8 81.1 81.1 1400.0 1400.0 O.ON O.OE 1404.6 13 99.6 81.58 2.3E 178.4 81. 5 81. 5 1500.0 1500.0 O.ON O.OE 1504.6 1499.5 82.18 1.5E 178.9 82.1 82.1 1600.0 1600.0 O.ON O.OE 1604.6 1599.5 82.78 0.7E 179.5 82.7 82.7 1700.0 1700.0 O.ON O.OE 1704.6 1699.5 83.38 0.4W 180.3 83.3 83.3 1750.0 1750.0 O.ON O.OE 1754.6 1749.5 83.68 0.9W 180.6 83.6 83.6 1762.5 1762.5 O.ON O.OW 1767.1 1762.0 83.68 1. OW 180.7 83.7 83.7 1775.0 1775.0 O.lN O.lW 1779.6 1774.5 83.78 1.2W 180.8 83.8 83.8 1787.5 1787.5 o .3N O.lW 1792.1 1787.0 83.88 1. 3W 180.8 84.0 84.1 1800.0 1800.0 0.5N 0.2W 1804.6 1799.5 83.88 1.5W 180.8 84.3 84.4 1812.5 1812.5 0.8N 0.3W 1817.1 1812.0 83.98 1. 6W 180.8 84.7 84.7 1825.0 1825.0 loIN 0.5W 1829.6 1824.5 84.08 1. 7W 180.8 85.1 85.1 1837.5 1837.5 1.5N 0.7W 1842.1 1837.0 84.08 1. 8W 180.8 85.6 85.6 1850.0 1850.0 2.0N 0.9W 1854.6 1849.5 84.18 2.0W 180.7 86.1 86.2 1862.5 1862.5 2.5N 1.1W 1867.1 1862.0 84.28 2.1W 180.7 86.7 86.8 1875.0 1874.9 3.1N 1.4W 1879.5 1874.5 84.28 2.2W 180.6 87.3 87.5 1887.5 1887.4 3.8N 1. 7W 1892.0 1886.9 84.38 2.4W 180.5 88.1 88.2 1900.0 1899.9 4.5N 2.0W 1904.5 1899.4 84.48 2.5W 180.3 88.9 89.0 1912.5 1912 .4 5.3N 2.3W 1917.0 1911 . 9 84.48 2.6W 180.2 89.7 89.9 1925.0 1924.8 6.1N 2.7W 1929.4 1924.3 84.58 2.7W 180.0 90.6 90.9 1937.5 1937.3 7.0N 3.1W 1941.9 1936.8 84.68 2.9W 179.9 91. 6 91. 9 1950.0 1949.7 8. ON 3.5W 1954.3 1949.3 84.68 3.0W 179.7 92.6 92.9 1962.5 1962.2 9.0N 4.0W 1966.8 1961.7 84.78 3.1W 179.5 93.7 94.1 1975.0 1974.6 10.lN 4.4W 1979.2 1974.1 84.88 3.2W 179.3 94.9 95.3 1987.5 1987.1 1l.3N 4.9W 1991.7 1986.6 84.88 3.3W 179.0 96 .1 96 .6 2000.0 1999.5 12.5N 5.5W 2004.1 1999.0 84.98 3.5W 178.8 97.4 97.9 2012.5 2011.9 13.7N 6. OW 2016.5 2011.4 85.08 3.6W 178.6 98.7 99.3 2025.0 2024.3 15.1N 6.6W 2028.9 2023.8 85.08 3.7W 178.3 100.2 100.8 2037.5 2036.7 16.5N 7.2W 2041. 3 2036.2 85.18 3.8W 178.1 101. 6 102.4 2050.0 2049.1 17.9N 7.9W 2053.7 2048.6 85.28 3.9W 177.8 103.2 104.0 e e 2062.5 2061. 5 19.5N 8.6W 2066.1 2061. 0 85.28 4.0W 177.5 104.8 105.7 2075.0 2073.9 21.1N 9.3W 2078.5 2073.4 85.38 4.1W 177.2 106.5 107.5 2087.5 2086.3 22.7N 10.0W 2090.8 2085.8 85.48 4.2W 177.0 108.2 109.3 2100.0 2098.6 24.4N 10.7W 2103.2 2098.1 85.48 4.4W 176.7 110.0 111.2 2112 .5 2111. 0 26.2N 11. 5W 2115.5 2110.4 85.58 4.5W 176.4 111.9 113.2 2125 . 0 2123.3 28. ON 12.3W 2127.8 2122.7 85.58 4.6W 176.1 113.8 115.3 2137.5 2135.7 29.9N 13 .2W 2140.2 2135.1 85.68 4.7W 175.8 115.8 117.4 2150.0 2148.0 31. 9N 14.0W 2152.5 2147.4 85.78 4.8W 175.5 117.9 119.6 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33~6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level: Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 15 Pad 41~7,KBU33~6X Your ref KBU33~6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 3~Oct~2003 Reference wellpath Object wellpath PM88 <8846 ~ 10960>"KTU24~6H,Pad 41~7 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2162.5 2160.3 33.9N 14.9W 2164.8 2159.7 85.88 4.9W 175.2 120.1 121.9 2175.0 2172.6 36.0N 15.8W 2177 .1 2172.0 85.88 5.0W 174.9 122.3 124.3 2187.5 2184.8 38.1N 16.8W 2189.3 2184.2 85.98 5.1W 174.6 124.5 126.7 2200.0 2197.1 40.3N 17.7W 2201. 6 2196.5 86.08 5.2W 174.3 126.9 129.3 2212.5 2209.4 42.6N 18.7W 2213 . 8 2208.8 86.08 5.3W 174.1 129.3 131.9 2225.0 2221.6 44.9N 19.7W 2226.1 2221. 0 86.18 5.4W 173.8 131. 8 134.5 2237.5 2233.8 47.3N 20.8W 2238.3 2233.2 86.28 5.5W 173.5 134.3 137.3 2250.0 2246.0 49.7N 21.9W 2250.5 2245.4 86.28 5.7W 173.2 136.9 140.1 2262.5 2258.2 52.2N 23.0W 2262.7 2257.6 86.38 5.8W 172.9 139.6 143.1 2275.0 2270.4 54.8N 24.1W 2274.8 2269.7 86.48 5.9W 172.6 142.4 146.1 2287.5 2282.6 57.4N 25.2W 2286.9 2281. 8 86.58 6.0W 172 .4 145.2 149.1 2300.0 2294.7 60.1N 26.4W 2299.1 2294.0 86.58 6.1W 172.1 148.1 152.3 2312.5 2306.9 62.9N 27.6W 2311.2 2306.1 86.68 6.2W 171.8 151. 0 155.6 2325.0 2319.0 65.7N 28.9W 2323.3 2318.2 86.78 6.3W 171.6 154.1 158.9 2337.5 2331.1 68.6N 30.1W 2335.4 2330.3 86.88 6.4W 171.3 157.1 162.3 2350.0 2343.2 71.5N 31.4W 2347.5 2342.3 86.98 6.5W 171. 0 160.3 165.8 2362.5 2355.2 74.5N 32.7W 2359.5 2354.4 86.98 6.6W 170.8 163.5 '169.4 2375.0 2367.3 77.5N 34.1W 2371.4 2366.3 87.08 6.7W 170.5 166.8 173.1 2387.5 2379.3 80.6N 35.4W 2383.4 2378.3 87.18 6.7W 170.3 170.2 176.9 2400.0 2391. 3 83.8N 36.8W 2395.4 2390.3 87.28 6.8W 170.0 173.6 180.8 2412.5 2403.3 87.1N 38.3W 2407.4 2402.2 87.38 6.9W 169.8 177 .1 184.7 2425.0 2415.3 90.3N 39.7W 2419.3 2414.2 87.48 7.0W 169.6 180.7 188.7 2437.5 2427.2 93.7N 41.2W 2431. 2 2426.1 87.48 7.0W 169.3 184.3 192.9 2450.0 2439.2 97.1N 42.7W 2443.2 2438.1 87.58 7.1W 169.1 188.0 197.1 2462.5 2451.1 100.6N 44.2W 2455.1 2449.9 87.68 7.2W 168.9 191.8 201. 4 2475.0 2463.0 104.1N 45.8W 2466.9 2461.8 87.78 7.2W 168.6 195.6 205.8 2487.5 2474.8 107.7N 47.3W 2478.8 2473.6 87.88 7.3W 168.4 199.6 210.3 e e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 16 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 3-0ct-2003 Reference wel1path Object we1lpath PM88 <0 - 7570>, ,KBU42-7,Pad 41-7 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 4.7 0.1 81.08 18.3W 192.7 83.1 83.1 100.0 100.0 O.ON O.OE 105.0 100.4 80.88 18.4W 192.9 82.8* 82.8* 200.0 200.0 O.ON O.OE 205.0 200.4 80.18 18.8W 193.2 82.3* 82.3* 300.0 300.0 O.ON O.OE 304.0 299.4 80.08 19.4W 193.6 82.3 82.3 400.0 400.0 O.ON O.OE 401.4 396.7 82.38 20.8W 194.2 84.9 85.0 500.0 500.0 O.ON O.OE 497 .1 492.2 87.78 23.1W 194.8 91.1 91.4 600.0 600.0 O. ON O.OE 593.6 588.3 96.78 26.2W 195.1 100.9 101. 6 700.0 700.0 O.ON O.OE 690.3 684.2 108.78 29.1W 195.0 113.7 114.8 800.0 800.0 O.ON O.OE 789.3 782.2 123.08 29.4W 193.4 127.7 129.0 900.0 900.0 O.ON O.OE 890.9 882.6 13 7.78 25.7W 190.6 141. 2 142.3 1000.0 1000.0 O.ON O.OE 993.3 983.9 151.08 18.5W 187.0 153.0 153.9 1100.0 1100.0 O.ON O.OE 1094.1 1083.6 162.28 8.9W 183.1 163.3 164.1 1200.0 1200.0 O.ON O.OE 1193.0 1181.4 172.68 1. 3E 179.6 173.6 174.6 1300.0 1300.0 O.ON O.OE 1291.4 1278.7 182.98 12.3E 176.1 184.6 185.8 1400.0 1400.0 O.ON O.OE 1387.5 13 73.4 193.68 23.8E 173.0 196.8 198.7 - e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KBU33-6X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1750.0 1762.5 1500.0 1600.0 1700.0 1750.0 1762.5 1775.0 1787.5 1800.0 1812.5 1825.0 1775.0 1787.5 1800.0 1812.5 1825.0 1837.5 1850.0 1862.5 1875.0 1887.5 1837.5 1850.0 1862.5 1874.9 1887.4 1900.0 1912 .5 1925.0 1937.5 1950.0 1899.9 1912.4 1924.8 1937.3 1949.7 1962 .5 1975.0 1987.5 2000.0 2012.5 1962.2 1974.6 1987.1 1999.5 2011.9 2025.0 2037.5 2050.0 2062.5 2024.3 2036.7 2049.1 2061. 5 O.ON O.ON O.ON O.ON O.ON O. ON O. ON O. ON O. ON O. ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.lN 0.3N 0.5N 0.8N 1.lN 1.5N 2.0N 2.5N 3.1N 3.8N 4.5N 5.3N 6.1N 7. ON 8. ON 9. ON 10.lN 11. 3N 12.5N 13.7N 15.1N 16.5N 17.9N 19.5N Object wellpath O.OE O.OE O.OE O.OE O.OE 4.5 104.3 203.4 303.7 404.0 O.OE O.OE O.OE O.OE O.OE 503.0 601. 3 700.1 800.4 902.3 O.OE O.OE O.OE O.OE O.OE 1003.3 1104.7 1206.6 1307.1 1407.1 O.OE O.OE O.OE O.OE O.OW 1508.3 1608.5 1708.0 1758.6 1771 .1 O.lW O.lW 0.2W 0.3W 0.5W 1782.6 1795.1 1807.6 1819.3 1831. 8 0.7W 0.9W 1.1W 1.4W 1. 7W 1843.8 1856.3 1868.8 1881. 0 1893.5 2.0W 2.3W 2.7W 3.1W 3.5W 1906.0 1918.4 1930.9 1943.0 1955.5 4.0W 4.4W 4.9W 5.5W 6.0W 1968.0 1979.8 1992.3 2004.1 2016.5 6.6W 7.2W 7.9W 8.6W 2029.0 2040.8 2053.2 2065.0 M.D. T.V.D. -0.1 99.7 198.7 299.1 399.4 498.4 596.5 695.0 794.9 896 .3 997.1 1098.5 1200.4 1300.8 1400.8 1502.0 1602.1 1701. 6 1752.2 1764.7 1776.2 1788.7 1801.2 1813.0 1825.5 1837.5 1850.0 1862.5 1874.7 1887.1 1899.6 1912.0 1924.5 1936.6 1949.1 1961.6 1973.4 1985.8 1997.6 2010.1 2022.5 2034.3 2046.7 2058.5 CLEARANCE LI8TING Page 17 Your ref KBU33-6X Version 2 Last revised: 3-0ct-2003 MWD <0-7440>"KBU 44-6,Pad 41-7 Rect Coordinates 85.98 85.88 85.48 84.88 83.98 82.48 79.08 73.18 65.78 58.68 53.18 50.18 47.98 47.08 47.88 49.18 50.28 51.38 51. 78 51.78 51.78 51. 78 51. 78 51. 68 51.58 51.48 51. 28 51.18 50.98 50.78 50.58 50.28 49.88 49.48 48.98 48.58 48.08 47.58 46.98 46.48 45.88 45.28 44.68 44.08 150.6E 150.8E 151.3E 152.4E 153.4E 154.9E 158.2E 163.7E 170.2E 175.4E 179.1E 181.2E 181. 9E 182.1E 181.3E 180.2E 178.7E 177 . 4E 176.6E 176.5E 176.3E 176.2E 176.2E 176.1E 176.1E 176.1E 176.2E 176.2E 176.3E 176.4E 176.5E 176.6E 176.7E 176.9E 177 . OE 177.3E 177 . 5E 177 . 7E 178.0E 178.3E 178.6E 178.9E 179.3E 179.7E Horiz Bearing 119.7 119.6 119.4 119.1 118.7 118.0 116.5 114.1 111.1 108.5 106.5 105.5 104.8 104.5 104.8 105.2 105.7 106.1 106.3 106.3 106.4 106.4 106.5 106.5 106.6 106.7 106.7 106.8 106.9 107.0 107.1 107.2 107.3 107.4 107.5 107.6 107.7 107.8 107.9 108.1 108.2 108.3 108.5 108.6 Min'm Dist TCyl Dist 173 .4 173.5 173.8 174.4 174.9 173.4 173.5 173.8 174.4 174.9 175.5 176.9 179.4 182.5 185.0 175.5 176.9 179.5 182.6 185.0 186.8 188.0 188.1 188.0* 187.5* 186.8 188.0 188.1 188.0* 187.5* 186.7* 185.6* 184.7* 184.1* 183.9* 186.7* 185.6* 184.7* 184.1* 183.9* 183.9* 183.9 183.9 184.1 184.3 183.9* 183.9 184.0 184.1 184.3 184.6 184.9 185.3 185.7 186.2 184.6 185.0 185.4 185.8 186.3 186.7 187.3 187.9 188.6 189.3 186.9 187.5 188.2 188.9 189.7 190.1 191.0 191.9 192.9 193.9 190.5 191.5 192.4 193.5 194.6 195.0 196.2 197.4 198.7 195.8 197.1 198.4 199.8 - e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LISTING Page 18 Pad 41-7,KBU33-6X Your ref KBU33-6X Version 2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised , 3-0ct-2003 Reference wellpath Object wellpath MWD <0-8610>, ,KBU43-7X, Pad 41-7 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 4.5 -0.1 3.98 45.3W 265.1 45.5 45.5 100.0 100.0 O.ON O.OE 104.0 99.4 3.48 45.9W 265.8 46.1 46.1 200.0 200.0 O.ON O.OE 203.5 198.8 1. 98 47.7W 267.7 47.8 47.8 300.0 300.0 O.ON O.OE 302.7 298.0 0.2N 50.8W 270.3 50.8 50.8 400.0 400.0 O.ON O.OE 399.5 394.6 1.7N 56.4W 271.7 56.7 56.9 500.0 500.0 O.ON O.OE 495.9 490.3 1.8N 68.1W 271.5 68.8 69.5 600.0 600.0 O.ON O.OE 593.8 587.1 0.4N 82.5W 270.3 83.5 84.5 700.0 700.0 O.ON O.OE 691.3 683.2 3.4S 98.1W 268.0 99.5 101.0 800.0 800.0 O.ON O.OE 788.5 778.9 9.1S 114 . 6W 265.5 116.9 118.9 900.0 900.0 O.ON O.OE 885.0 873.4 17.48 131.9W 262.5 135.7 138.5 1000.0 1000.0 O.ON O.OE 976.8 962.8 28.58 149.9W 259.2 157.1 162.0 1100.0 1100.0 O.ON O.OE 1068.7 1050.9 44.98 169.9W 255.2 182.5 189.9 e e All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot KBU33-6X and TVD from RKB (Nabors 129) (82.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 333.58 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e Created by bmÎchoel For: S Lambe Dote plotted: 3-0ct-200J Plot Refer'ence is KBU33-6X Version 2. MARATHON Oil Company Coordinates ore in reet reference slot KBU33-6X. True Vertical Depths ore reference RKB (Nabors 129). r~illlll BAKER HUGIES TNTEQ 1100~' 1000- ~ ~"': ~, '~, '~ ~ ~ I I 1400 2200 2100 - 2000 - 1900 - 1800 - 1700 - 1600 - 1500 - ^ I 1400 - ..----, +- Q) Q) '+- "--'" 1300 - ...c +- L o Z 1200 - 900 - BOD - 700 - 600 - 500 400 - 300 1400 Structure : Pad 41-7 Well: KBU33-6X MARATHON Field : Kenai Gas Field Location: Kenai Peninsula. Alaska <- West (feet) 1300 100 200 2200 1200 1100 1000 900 BOD 700 400 300 200 100 o 600 500 ~ \1.\ ill '-. 6900 ~ 6600 I '~6600 '\ J "- \\, 4200 ¿ 4200 ,,6300 \ \ I ~6000 \ ~O I El '~~~OO \ 60~ I '0 7500 ",",5400 \ I , ù 7200 ~ \ 3901 . 3900 '" 6900 .5100 \ 5700 . '-0 6600 \ \ , ù 6300 \ \ , \ \ " 6000 \ 5400 \ "" 5700 \ I " ù 5400 \ ! , \ . 3600 Ò, 5100 \ 5100 ~ \ \.4800 \ \ \4200 I \ \ \ 4800 \.. 4500 \ \ 0 3300 \ \ \ \ \ 3900 \ \. ; \ \ ~ 4500 'ì 4200 \ \ \ \ \ \ \ 3600 \ \ \ \ \ \ \ 4200 \ 39¿\ \ \ 3300 \ \ \ \ \ \ ~ 35100700 \ \ \ \ \ \ 3000 \ \ \ 3'00 '\ \ t 360\ \ '\ \ 2400 \ ,2700 \ \ \\ ! \ , \ \ "\ ~ 3300 \ \ \ \'\N8P \ ~ 'í . \ \ \ \ 2100 \ \ \ . \ \ ~ 3000 \ '\ \ \ 2~ ~O \ ~~, ~, - 2100 - 2000 - 1900 - 1BOO - 1700 - 1600 - 1500 - 1400 ^ I z o ..., -+ ::r - 1300 o 3000 - 1200 ..----, -+. (1) (1) -+ "--'" - 1100 - 1000 - 900 - BOD - 700 - 600 500 - 400 300 200 1300 1200 1100 100 o 100 1000 900 BOD 700 600 500 400 300 200 <- West (feet) e e Created by bmlchoel For: S Lambe! True Verllco! Oepths ore reference RKB (Nabor! 129) Structure : Pod 41-7 Well: KBU33-6X Oate plotted; 3-0ct-2003 MARATHON Oil Company Plot Reference is KBU33-6X Version 2. Coordinates ore in reet referef\Ce slot KBU33-6X, BA HU TNTEQ MARATHON Field : Kenai Gas Field Location : Kenai Peninsula, Alaska ~ 290 m ì ì \ \ \ 182Y30 \ \ 320\ ì \ \ 350 TRUE NORTH ~.~ ~ ~,6300 "~ \ 10" ~ 45~0 \ ~C{9 210 ~800 \ \ ----~OO \ \ 30 340 40 310 50 300 70 280 80 270 90 260 100 240 190 180 ~ ~oqj 20 ~OO \~® \ 140 \ \ J50 ~ 160) 60 \- 300 J' \ \ ¡ 300 \ 900 %~{jj <& l 230 220 210 200 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well e Project Summary Casing Hole Size Size (in) (in) Casing Program 13 3/8" 16" 5/8" 12-114" 8-112" Depth TVD e Marathon Oil Company Well Name: KBU 33-6X Location: Kenai, Alaska. Mud Mud Sum System Days SólidsControl Interval Mud Cost (ft) (ft) 1500' GellGelex Spud 8.6 - 9.4 5 Mud Screens 150/180 mesh Desilter Centrifuge Van $145,178 5790' 5250' Flo-Pro 9.0 - 9.6 wlSafeCarb Screens 180 210 mesh Desilter Centrifuge Van $92,205 8319' 7725' Flo- Pro w/SafeCarb 10.0+ Screens 230 mesh Desi Centrifu 6% KCI $8,516 8.55 ~ Utilize all solids control equipment to minimize the build up of drill solids in the system (if possible, centrifuge the surface mud during trips to reduce drill solids). ~ Condition the mud prior to running casing for all intervals. ~ Cost does not include any considerations for whole mud losses. IÆ e e - ~IFE Marathon Oil Company Well Name: KBD 33-6X Location: Kenai, Alaska. Interval Summary -16" hole Drilling Fluid System GellGelex Spud Mud MI Gel / Gelex / Soda Ash / Caustic Soda / MI Bar / PolyPac Supreme UL Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens -150 -180 mesh PotentiâlProblems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions API Fluid Loss (mI/30min) 0- 1500' 8.6 - 9.2 60 - 100 25 - 35 NC - 12 +/- 9.5 <7% ~ Treat drill water with Soda Ash to reduce hardness. ~ Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 sec.qt funnel viscosity. ~ Lower funnel viscosity to +/- 75 after gravel zone has been drilled. ~ Add Gelex as needed to maintain sufficient viscosity for hole cleaning. ~ Increase funnel viscosity if fill on connections begins to occur. ~ Reduce fluid loss with additions ofPolypac Supreme UL prior to running surface casing. ~ Add 2 - 5 PPB ofM-I Seal Fine to mud system if seepage losses becomes a problem.. ~ Condition mud prior to cementing casing to reduce yield point and gel strengths. ~ Estimated volume usage for interval- 1519 barrels. ~ Estimated haul off volume - 2992 barrels. IÆ e e - 1,;1IFE Marathon Oil Company Well Name: KBU 33-6X Location: Kenai, Alaska. Interval Summary - 12-1/4" hole Drilling}i7lnidSystem Flo-Pro Fluid KeyProducts Flo- Vis / PolyPac UL / KCl / SafeCarb F & M, Asphasol Supreme / Lubetex / KlaGard / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 mesh PotentiâLProbIems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Depth Interval (ft) 1500 - 3500' 3500 - 5790' Mud ht pg) 9.0- 9.4 9.2 - 9.4 8-12 10 - 14 LSRV 1 mi (c 40,000 40,000 API Fluid Loss (mV30min) 8 - 10 7-9 +/- 9.5 +/- 9.5 lids 0) +/- 5% +/- 8% ~ Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. ~ After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak offtest. ~ Maintain DO reading of less than 3 ppm with additions of SaveScav NA. ~ Maintain Conqor 404 concentration of 2000+ ppm. ~ If running coals become a problem, treat with a 2 PPB addition of Asphasol Supreme ~ Estimated volume usage for interval- 2618 barrels. ~ Estimated haul off volume - 5000 barrels. ~ Condition mud prior to running 9-5/8" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. IÆ e e IFE Marathon Oil Company Well Name: KBU 33-6X Location: Kenai, Alaska. Interval Summary - 8-1/2" hole Drilling Fluid System Flo-Pro Fluid Flo- Vis / DualFlo / KCl / Greencide 25G / SafeCarb F, KlaGard / MI Bar / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 - 230 mesh PóterttiälProblems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Depth Interval (ft) 5790 - 8319' Mud Weight (ppg) 9.2 - 9.4 Plastic Viscosity (cp.) 10 - 14 40,000 <5 +/- 9.5 +/- 5% ~ Use one rig pit for drilling out intermediate casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. ~ If running coals become a problem, treat with a 2 PPB addition of Asphasol Supreme. ~ Periodic additions of Greencide 25G will be needed to control bacteria build-up. ~ Estimated volume usage for interval- 1464 barrels. ~ Estimated haul off volume - 2355 barrels. ~ Condition mud prior to running 3-112" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. IFE e e Surface Use Plan for Kenai Beluga Unit, well KBU 33-6X Surface location: Anticipated at 65' FSL, 4,133' FWL, Sec. 6, T4N, R11W, S.M. 1) Existing Roads Existing roads which will be used for access to KBU 33-6X are shown on the attached map. Kenai, Alaska is the nearest town to the site and is also shown on the map. 2) Access Roads to be Constructed or Reconstructed No new roads will be required to access KBU 33-6X. 3) Location of existing wells Well KBU 33-6X will be drilled on Kenai Gas Field (KGF) pad 41-7. A pad drawing is enclosed that shows existing wells and the proposed location of KBU 33-6X. 4) Location of existing and/or proposed facilities The locations of existing production facilities in the KGF pad 41-7 are shown on the enclosed pad drawing. These facilities will be upgraded to handle the additional gas production. 5) Location of Water Supply A water supply well exists on the pad that KBU 33-6X will be drilled from. This is shown on the pad drawing. 6) Construction Materials No construction is planned on the pad. The recent pad expansion has already been completed and is sufficient. 7) Methods of handling waste disposal; a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendors that provided them. Efforts will be Ie e made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8) Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Sand R will collect and transport sanitary wastes to their ADEC approved disposal facility. 9) Plans for reclamation of the suñace KBU 33-6X will be drilled from an existing pad. Reclamation of the pad will occur after the abandonment of KBU 33-6X and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from the U.S. Fish and Wildlife Service prior to any reclamation work beginning. 10) Suñace ownership The surface owner of the land in the Kenai Beluga Unit is the CIRI Native Corporation. 11) Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that 1 am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: ICJlz( (030 Name and Title: Steven S. Lambe, Senior Drilling Engineer Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6332 , Beluga/Upper Tyonek Completion ..... + MILE HM4094 0: \free h a n d\ke nal\be I uga\kb u 33-6x_loç.fi11Q e 1J 5/8" 5000/.. WP HI'DIM. TYPE: "G1(" 1J 5/8" 5000# WP scREwED TOP BY I J 5/8" FlANGED E1OT1OM INNUUR BOP HEIGHT - 51.25" MANtW.LY OP£'RA7ED 2-1/16" 5,0001 iff' GATE VAL~ - - 2" IOU. LINE 1J-5/8" 5000/ N'I FlANGED TOP AND BOTTOf, _ IoItJO CROSS W/ 0Nf 0) 4-1/16" (CHOKE UNEl ct 0tiE:'(1) J-I/16" (KILL UN£) 5,000/ N'I FlANGED OUTlETS ~~." ~ Nt>t- P. yq P.. Ot<J ~ ~ 1.&J6+- - 30" / w.NVAU.Y OP£'RA7ED 2- 1/16" 5,0001 WP GATE VALvt . '1 j I I I I I . I . 1._...JUl iuLI []U~ '~~JD "II\/-f1IJ LJ !_, ~,H.J L DlJr'ml 111~j1r] t-lI:JJl.tl-+::JJ+l~J r 1J-5/8" 5fXJOI HYDRIL OOUBI.E GATE PR£IÆNroR IJ-5/8" 5000# lIP \ FlANGED TOP AND BOTTOf, HEIGHT - 54" HYfJRAULAC1U47ED ~ 3-1/16" 10.o0oi lIP ~ r:rr- GATE VAL~ \ ~ J" CHOKE I./NE- - ~ NANlJM.LY OP£'RA7ED 3-1/16" 5.0001 iff' GATE VAL~ 10'-91" e NABORS ALASKA RIG 129 BOP STACK CONFIGURATION .ua...... ....."-P ..,.... ','1&"' ....~ . F+"i-=::!- . _ AIASII'A II/Q I. ... IIlI1IIINT I'IIMM!1t SIØ C/1IØJIAIA1Ø# -A_L""'_¡-"' __1"- -' ~ r..·' IIIIT_ r-.... "'--I ., - - ....9 ~x." MUD MIX HOPPER .. r~ MUD MIX HOPPER ~ . . ~ ." e · t '" LEGEND -0- CONCENTRIC REDUCER _ GATE VALVE --ItIJ- BUTTERFLY VALVE CIW FLANGES -Q- SUCTION VALVE. TEE TYPE -ç¿ SUCTION VALVE, ELL TYPE 1 1 r .. DESILTER '" ® BOTTOM MUD GUN LOW PRESSURE TYPE X AGITATOR ~K EQUALIZER ~ g;r SKIMMER WEll. RETURNS NABORS ALASKA RIG 129 MUD SYSTEM SCHEMATIC , r . "r.1,Ç k---, '~ .., r -.:r---;ó" 41 .) '" V · º ^ ." . º r º @".. tþ ~; 'Ð! m ~ . · ~_I{I.r ..... I r. I ". . DISCHARGE r..., '" MANIFOLD IS' x r · . ~J ~ '" ... .. ~! ':'" ,.;:«J!-f' v~ =-fIIIC-, ~. CENiRI~~LS 5" x r f'¡~ r ~~" ..... X º S'xr-..r . ºr " .. ... ." xl} ~ º I"'~J" 1::/ PILL TANK '" 8" FLOW LINES TO MUD PUMPS .. 12". ..'Z" 8.. NOT SHOWN ARE TANK CLEANOUTS SUMP SUCTION OR STEAM LINES ,../ ~ "~j"" ~ I TO SUMP , SHALE SHAKE~ r-:HALE SHAKER L~J --wk-. -=r-r0" ~. 7~0"~~ 1 01 o o' ~o"L ºlx ~ l' ~........ ~ I~ x . r º r º I"i!" ~J" '" · ºv ,.^ . ~ .. ·x . . ~J" =J"~~J" J" - --I: FROM 196 IIbto II MANIFOLD 244 SbbI 0 ,:.r 36" MUD GAS SEPARATOR II< rxJ" ".. D .1 '" '" II< . ~O FLARE -' 'TOTAL ACTIVE VOLUME = 1183 BbIS.' TOTAL GROSS VOLUME = 1470 Bbls. 1"'. A:-'""" M'-"........UI. '" .,...,.... ='0'= =-.: . ~-- IMJIS AIASIrA ~ 121 IIIJI SISIDI SCIÐIIQIÇ IIID _ N:1M SISIDI -AAIsrtIW;;;:_~· __~- - ~ _I...· ... J2UIIJ I~ " , ACTIVE EQUALS VOLUME TO BOTTOM OF MUD DITCH GROSS EQUALS VOLUME TO FULL HEIGHT OF TANK ( NOT INCLUDING TRIP TANK) 1. ft< REF: ~ ~D£SIQII L1II.... .... "II'- - . I '" 8 . . e 11II& 'III""l"""-- 'II'Ir.IrI'IIIIm or ...,........ ~=~ ...., -- . ~ " NMIfJRS AIA5IrA /I1/) In till GØtÐW NIRNIIJDENf fl" /MR'IEI! SISIEII _ A .u. p.r. --c..-UII;"-Iß"~ -"'_1....._1-. __l....A - It... 'II'" - ..... 11I4\ - .l/2llllJ1....... '1J..ÐtI//I~"" e- t ~ .J~~ '~'I~~ x ~ ~ ,r III I" niP' _ . _ 'It. I ,..----, ^. ~WF ~ r < ye~~ 8IIt= hi rQ( ~=~) ~_w . . . I I e ~ ~1:"~ NABORS ALASKA RIG 129E GENERAL ARRANGEMENT - - ¡==" - - - = ===- - - ¡:::=:::¡ - - - = =~.^' -I~ = IM/IIÐI SFOa. NIl 21 1/4"-_ FINIGES I. IM/IIÐIIIIIWB MllllMlLY CRJW. I. __1£ MllllMlLY aœm j.-.-., - . ,,- i£i&1ISP .._..~~-_.- IIIIWB I, Iii I "-- I¡"'-;'··-..- I: . I r·....J: li!ï"-' ~-+-jô -- I I I I "..1£ If" ~ .. !_I£ IW5I 1$0 FIJHIIfS DIVERTER CONFIGURAnON f l II \ e 'M..) "'!arathon . .MARATHON 011 Company tit Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 October 24, 2003 Sarah Palin Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application Field: Kenai Gas Field Well: Kenai Beluga Unit - KBU 33-6X Dear Ms. Palin Enclosed please find the PERMIT TO DRILL application, along with the associated attachments and filing fee of $100. The intent is to drill a development well in the Kenai Beluga Unit. Please note that Marathon is requesting a waiver for 20 ACC 25.035 (e) (1) (b) requiring a two pipe ram stack../ The requests are specified on page 11 of the attached drilling prognosis. If you require further information, I can be reached at 907-564-6332 or bye-mail at sslambe@marathon.com. sin7/-;z;L ~ Steven S. Lambe Senior Drilling Engineer Enclosures 9 4 '..~ ORIG\NAL e "';·¡'¡';'1T;c¡~¡;,,"·..'~T¡'"¡'¡i:¡~~;:lmr'1!'~¥Jln'.t~t.'~n;tf~:Wf}:t-'1~*~"3'mmlll'n~Jn~rJi1fitJ;m'lJ:t:~~tf~~~frflf~'~~m~:.Trn_ 111000 ~O 1111 2 ~BIII ':0 I. ~ 20 jB 11 5.: 0 ~B j t.B 1.111 e ~~1'-.~~~·~~~~··8~¡:\::~··..··..··· ;'''.ì.1,..'''~.;. COMMISSION 333 WeS1T'"~ ÞifAE ANCtìtOR~.E,4K· 995 56·389/412 Marathon Oil Compan SQ 7780 III' ~ [I). tf~'-1: 'I~' II ~i-"I¡I~';¡ ~tl ~ [tJ:,~, ~II ~~~ ~I ~ t ~I =f tj:I::( tt~'.=f~'tf~(ti :[11IJ NI.~' ;,J:~ I ~"l [11 11:11..: I. =till ~.I:I :1=1 1\'1'1'.11'] ~~ t~, I ~t:t 1'1 I [lit ;~I~ :¡;¡ I~' 't ~r.r: -- F'ÕRM2ŠÓ'1 RÉV. 5/00..·· ..- . _,,----'-'-"------"--~-'--------- . ., .'----..--------,--,..- · e TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/P ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wellbore segment of existing weD ~ Permit No, API No. Productionsbould continue to be reported as a function' of tbe original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PD.-OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/]0/02 C\jody\templates Tbe permit is approved subject to full compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing . exception tbat may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals tbrough target zones. Company MARATHON OIL CO Well Name: KENAI BELUGA UNIT KBU-33-6X Program DEV Well bore seg D PTD#: 2031830 Field & Pool KENAI, C.L.U. BELUGA GAS - 448575 Initial Classrrype DEV 11-GAS GeoArea Unit On/Off Shore ~ Annular Disposal D Administration P~(lTJitfee attache.d. . . · .Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . - - - - - - - - 2 .Leas~numberappropriate . - - - - - - - - - ~ - · .Y~s. . . . . . . . . - - - - - - - - - - - - - - - - - - - - - 3 .U.nique well. n.a[TI~ .aod Ol!lTJb.er . . . . . . . . . . . . . . . . . . . . · .Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - -. . - - - - - - - - -- 4 Wen IQcat~d ina. defil1e~Lpool - - - - - - - - - - - - - - - - - .No . . . . . . . KENAIBELUGA GASPOQLJS UNDEfINED,.CQ H5.SETSUNLJMITED SP.L\CINGFQRALLKENAI fiELD GAS 5 WeJIJQcat~d proper distance. from driJling ul1itb.oUl]d<il)'. . . . . . · .Y~s . . . . . . INCLUDING THIS UNDEfiNED JNTEHYAL;.MQC H.L\$ RECENT .L\PE>LIED TO DEFINE "[HE BELUGA.& UE>F'ER 6 WeJIJQcat~d pr.oper .distance. from otber welJs. · Xes..... .TYQNEKAS.L\SINGL.EF'QQL 7 Sutficiel1tacreage.ayailable in.d.rilliog unjl. . . . . . . . . . . . . · .Y~s. . . . . . . . . 8 Jfdeviated, js weJlbore platiocJuded . . . . . . . . . . . . . . . . . · .Y~s. . . . . . . . . . - - - - - - - - - - - - 9 O-perator ooly affected party . - - - - - - - - - - - - - - - - - - - · .Y~s - - - - - - - - - - - 10 .O-perator bas.appropriate.b.ond inJorce . . . . . . . . . . . . . . . · .Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P~(lTJit cao be iSSl!ed witbQut co.nserva.tiOI1 order. . . . . . . . . . · .Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 12 P~(lTJitC<élo be issl!ed witbQut ad.lTJioistratÌlle.appn:>vaJ . . · .Y~s.. - - - - - - - - - - - - RPC 10/27/2003 13 Can permit be approved before 15-day wait Yes 14 WenJQcated withil1 area and.strata .authorized by.lojectioo Ord~( # (putlO# in.commeots).{For. NA . . . . . . . - - - - - - - - - - - -- e 15 AJI welJs. withi.n .1l4.l1Jile.area.of reyiew jd~otified (Fo( servj~ well ol1ly). . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 P.re-produ.ced iojector; s:luratio.n.of pre--p(os:luctiOI1I~ss. than. 3 montbs. (For.servlce well onJy) . . .NA . . . . . - - - - - - - - - - - - 17 ACMP.FJnding.ofCon.si.steocy.has bee.nissuedfor.tbis pr.ojeçt . . . . . . . . . . . . . . . ... .NA................... Engineering 18 .C.oodu.cto( st(ing.p.rQvided . . . . - - - - - - . . . . . . . . . . . . . . . . . . .Y~s . . . . . . .20" @ 120~.. . . . . 19 .S.ucrace .casil]g.p.rotects alLk.nown USQWs . . - - - - - - - - - - - - - - - - - - .Y~s. . . . . . . . . . . . . . . . . . . 20 .CMTvotadeQu.ate.to çircutate.o.n.cood.uctor.& su.rf.q;g . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . .L\de.quate excess, . 21 .CMT v.ol adeQu.ate.to tie-lnlong .striog to.sucr csg. . . . . . . . . . . . . . . . . . . . . . .. N.o................ 22 .CMTwiIJ coyeraJl kl1o.w.npro.ductiye bQrilOn.s. . . . . .Y~s. . . . . . - - - - - - - - - - - - - - - - - - - - 23 .C.asiog desigos ad.equa.te fo( C,.T" B.&.Rerl1Jafrost . . . . . . . . . . . . . . . . . . . . . . . . .Y~s. . . . - - - - - - - - - - - - - - - 24 .As:lequate.tankage.o.r re.serve pit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . Nab.ors 1.29.. . . . . . . . . . . . . 25 Jf.a.re-d(ilt has.a. 1.0:403 fQr abandonlTJe.nt be~o apPJoved . - - - - - - - - - - - - - - - - - . . .NA . . . . . . . New well, . . 26 As:lequ<ite.wellboreseparatjo.n-pro-poses:l. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s _ . . . . . . . . . . . . . . _ . . . . _ . . . . . . 27 Jf.djverter .req.ui.red, dQes jt meet. reguJatiol1s. . . . . . . . . . . . . . . . . . . . . . . .Y~s. . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 28 .D.riUiog flujd. prQgralTJ schematic.& eq.uip Jistadequate. . . . . . . . . . . . . . . .Y~s. . . . . Max MW 10,0.ppg.. . . . . . . WGA 10/27/2003 29 .B.OPEs,.d.o.they meetreguJatioo . - - - - - - - - - - - - - - .Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . 30 .BOPE.press ra.ti[lg ap.p(op(iate; .test to .(pu.t psig i.n .commeots). . . . . . . . . . . . . . . .Y~s. . . . . . . Testto.35QO.psi. .MSF' 34.33 psi. e 31 C.hoke.l1Janjfold cQITJPJies w/APtRF'-53 (May 84) . . _ . . . . . . . . . . . . . .Y~s. 32 WQrk will occ.U( withoul.operation .shutdown. - - - - - - - - - - - - - - - - . . .Y~s. . . . . . . . . 33 Js presence. Qf H2S gas. prob.able. . . . . - - - - - - - - - - . . . . . . No. 34 MeçbanicaLcooditioo of wells withil1 ~OR yerified (for.s.ervice welJ only) . . . . . . . . . . . . . NA . . . . . . Geology 35 P~(mit. cao be i.sSl!ed w/a. hyd(ogen. s.ulfide meaS.ll(es. . . . . . . . . . . . . . . . . . . . . .Y~s. . . . 36 .D.ata.p.reselJted on pote.ntial pve.rpressurezooe$. - - - - - - - - - - - - - - - - NA. Appr Date 37 .S~i$mica.nalysjs. Qf sbaJlow gas.zooes. . . . . . . . . . . . . . . . . . . NA....... . RPC 10/27/2003 38 .S~abed.cOl1djtioo Sl!rvey.(if off-shoœ) . . . . . . . . . . . . . . . . . . . . . . . . .... ..NA 39 . CQnta.ct nam.elphoneJor.weekly progress. reports [exploratpl)' .ooly] . . . . . . . . . . . . . . NA . . Geologic Engineering Public AV~ Commissioner: Date: Commissioner: Date Commissioner ð70 Date 2? q Jj TS- 'O}~~k ~ st~